EPM 2200

Transcription

EPM 2200

Digital Energy
Multilin
EPM 2200 Multi-function Power
Metering System
Chapter 1:
Instruction Manual
Software Revision: 1.01
Manual P/N: 1601-9111-A2
Manual Order Code: GEK-113575A
Copyright © 2011 GE Multilin
RE
ISO9001:2000
G
EM
Canada L6E 1B3
I
N
215 Anderson Avenue, Markham, Ontario
U LT I L
GE Multilin's Quality
Management System is
registered to ISO9001:2000
Tel: (905) 294-6222 Fax: (905) 201-2098
Internet: http://www.GEmultilin.com
*1601-9111-A2*
D
T
GIS ERE
GE Multilin
QMI # 005094
LISTED
Table of Contents
1: THREE-PHASE
POWER
MEASUREMENT
THREE-PHASE SYSTEM CONFIGURATIONS ........................................................................... 1-1
WYE CONNECTION .............................................................................................................. 1-1
DELTA CONNECTION ........................................................................................................... 1-3
BLONDELL’S THEOREM AND THREE PHASE MEASUREMENT ......................................... 1-5
POWER, ENERGY AND DEMAND ............................................................................................... 1-8
DEMAND ............................................................................................................................... 1-10
REACTIVE ENERGY AND POWER FACTOR ............................................................................. 1-12
REAL, REACTIVE, AND APPARENT POWER ........................................................................ 1-12
POWER FACTOR ................................................................................................................... 1-13
HARMONIC DISTORTION .............................................................................................................. 1-14
INDUCTIVE AND CAPACITIVE IMPEDANCE .......................................................................... 1-15
VOLTAGE AND CURRENT MONITORING ............................................................................ 1-15
WAVEFORM CAPTURE ......................................................................................................... 1-16
POWER QUALITY .............................................................................................................................. 1-17
2: OVERVIEW AND
SPECIFICATIONS
HARDWARE OVERVIEW ................................................................................................................. 2-1
VOLTAGE AND CURRENT INPUTS ...................................................................................... 2-1
ORDER CODES ..................................................................................................................... 2-2
MEASURED VALUES ............................................................................................................ 2-2
UTILITY PEAK DEMAND ....................................................................................................... 2-3
SPECIFICATIONS ............................................................................................................................... 2-4
3: MECHANICAL
INSTALLATION
INTRODUCTION ................................................................................................................................ 3-1
ANSI INSTALLATION STEPS .......................................................................................................... 3-3
DIN INSTALLATION STEPS ........................................................................................................... 3-4
4: ELECTRICAL
INSTALLATION
CONSIDERATIONS WHEN INSTALLING METERS ................................................................. 4-1
CT LEADS TERMINATED TO METER ................................................................................... 4-2
CT LEADS PASS-THROUGH (NO METER TERMINATION) ................................................ 4-3
QUICK CONNECT CRIMP CT TERMINATIONS ................................................................... 4-3
VOLTAGE AND POWER SUPPLY CONNECTIONS .............................................................. 4-4
GROUND CONNECTIONS .................................................................................................... 4-5
VOLTAGE FUSES .................................................................................................................. 4-5
ELECTRICAL CONNECTION DIAGRAMS .................................................................................. 4-6
DESCRIPTION ........................................................................................................................ 4-6
(1) WYE, 4-WIRE WITH NO PTS AND 3 CTS, NO PTS, 3 ELEMENT ............................ 4-7
(1A) DUAL PHASE HOOKUP ............................................................................................... 4-8
(1B) SINGLE PHASE HOOKUP ............................................................................................ 4-9
(2) WYE, 4-WIRE WITH NO PTS AND 3 CTS, 2.5 ELEMENT ........................................ 4-10
(3) WYE, 4-WIRE WITH 3 PTS AND 3 CTS, 3 ELEMENT .............................................. 4-11
(4) WYE, 4-WIRE WITH 2 PTS AND 3 CTS, 2.5 ELEMENT ........................................... 4-12
(5) DELTA, 3-WIRE WITH NO PTS, 2 CTS ....................................................................... 4-13
(6) DELTA, 3-WIRE WITH 2 PTS, 2 CTS ......................................................................... 4-14
(7) DELTA, 3-WIRE WITH 2 PTS, 3 CTS ......................................................................... 4-15
EPM 2200 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
TOC–1
(8) CURRENT-ONLY MEASUREMENT (THREE-PHASE) .................................................... 4-16
(9) CURRENT-ONLY MEASUREMENT (DUAL-PHASE) ...................................................... 4-17
(10) CURRENT-ONLY MEASUREMENT (SINGLE-PHASE) ................................................ 4-18
5: COMMUNICATION
INSTALLATION
EPM2200 COMMUNICATION ...................................................................................................... 5-1
RS-485 / KYZ OUTPUT COM 2 (485P OPTION) ........................................................ 5-1
EPM2200 COMMUNICATION AND PROGRAMMING OVERVIEW .................................. 5-5
FACTORY INITIAL DEFAULT SETTINGS ............................................................................... 5-5
ADDITIONAL EPM2200 PROFILE SETTINGS ................................................................... 5-8
6: USING THE METER
INTRODUCTION ................................................................................................................................ 6-1
METER FACE ELEMENTS ..................................................................................................... 6-1
METER FACE BUTTONS ....................................................................................................... 6-2
% OF LOAD BAR ............................................................................................................................... 6-4
WATT-HOUR ACCURACY TESTING (VERIFICATION) ........................................................... 6-5
INFRARED & KYZ PULSE CONSTANTS FOR ACCURACY TESTING ................................. 6-6
7: CONFIGURING THE
METER USING THE
FRONT PANEL
OVERVIEW ........................................................................................................................................... 7-1
START UP ............................................................................................................................................. 7-3
CONFIGURATION .............................................................................................................................. 7-4
MAIN MENU ........................................................................................................................ 7-4
RESET MODE ....................................................................................................................... 7-4
CONFIGURATION MODE ...................................................................................................... 7-6
CONFIGURING THE SCROLL FEATURE ............................................................................... 7-7
PROGRAMMING THE CONFIGURATION MODE SCREENS ................................................ 7-7
CONFIGURING THE CT SETTING ........................................................................................ 7-9
CONFIGURING THE PT SETTING ........................................................................................ 7-10
CONFIGURING THE CONNECTION (CNCT) SETTING ......................................................... 7-11
CONFIGURING THE COMMUNICATION PORT SETTING .................................................... 7-12
OPERATING MODE ............................................................................................................... 7-14
APPENDIX A: EPM2200
NAVIGATION MAPS
INTRODUCTION ..................................................................................................................APPENDIX A-1
NAVIGATION MAPS (SHEETS 1 TO 4) ..........................................................................APPENDIX A-2
EPM2200 NAVIGATION MAP TITLES: ...............................................................APPENDIX A-2
APPENDIX B: MODBUS
MAPPING FOR
EPM2200
INTRODUCTION ..................................................................................................................APPENDIX B-1
MODBUS REGISTER MAP SECTIONS ........................................................................APPENDIX B-2
DATA FORMATS .................................................................................................................APPENDIX B-3
FLOATING POINT VALUES .............................................................................................APPENDIX B-4
MODBUS REGISTER MAP ................................................................................................APPENDIX B-5
TOC–2
Digital Energy
Multilin
Metering System
Chapter 1: Three-Phase Power
Measurement
Three-Phase Power Measurement
This introduction to three-phase power and power measurement is intended to provide
only a brief overview of the subject. The professional meter engineer or meter technician
should refer to more advanced documents such as the EEI Handbook for Electricity
Metering and the application standards for more in-depth and technical coverage of the
subject.
1.1
Three-Phase System Configurations
Three-phase power is most commonly used in situations where large amounts of power
will be used because it is a more effective way to transmit the power and because it
provides a smoother delivery of power to the end load. There are two commonly used
connections for three-phase power, a wye connection or a delta connection. Each
connection has several different manifestations in actual use.
When attempting to determine the type of connection in use, it is a good practice to follow
the circuit back to the transformer that is serving the circuit. It is often not possible to
conclusively determine the correct circuit connection simply by counting the wires in the
service or checking voltages. Checking the transformer connection will provide conclusive
evidence of the circuit connection and the relationships between the phase voltages and
ground.
1.1.1
Wye Connection
The wye connection is so called because when you look at the phase relationships and the
winding relationships between the phases it looks like a wye (Y). Fig. 1.1 depicts the winding
relationships for a wye-connected service. In a wye service the neutral (or center point of
the wye) is typically grounded. This leads to common voltages of 208/120 and 480/277
(where the first number represents the phase-to-phase voltage and the second number
represents the phase-to-ground voltage).
1–1
CHAPTER 1: THREE-PHASE POWER MEASUREMENT
Ia
A
Van
Vbn
B
Vcn
N
C
FIGURE 1–1: Three-phase Wye winding
The three voltages are separated by 120o electrically. Under balanced load conditions with
unity power factor the currents are also separated by 120o. However, unbalanced loads
and other conditions can cause the currents to depart from the ideal 120o separation.
Three-phase voltages and currents are usually represented with a phasor diagram. A
phasor diagram for the typical connected voltages and currents is shown below.
Vcn
Ic
Van
Ia
Ib
Vbn
FIGURE 1–2: Three-phase Voltage and Current Phasors for Wye Winding
The phasor diagram shows the 120° angular separation between the phase voltages. The
phase-to-phase voltage in a balanced three-phase wye system is 1.732 times the phaseto-neutral voltage. The center point of the wye is tied together and is typically grounded.
1–2
The following table indicates the common voltages used in the United States for wye
connected systems.
Table 1–1: Common Phase Voltages on Wye Services
Phase-to-Ground Voltage
Phase-to-Phase Voltage
120 volts
208 volts
277 volts
480 volts
2400 volts
4160 volts
7200 volts
12470 volts
7620 volts
13200 volts
Usually, a wye-connected service will have four wires: three wires for the phases and one
for the neutral. The three-phase wires connect to the three phases. The neutral wire is
typically tied to the ground or center point of the wye (refer to the Three-Phase Wye
Winding diagram above).
In many industrial applications the facility will be fed with a four-wire wye service but only
three wires will be run to individual loads. The load is then often referred to as a
deltaconnected load but the service to the facility is still a wye service; it contains four
wires if you trace the circuit back to its source (usually a transformer). In this type of
connection the phase to ground voltage will be the phase-to-ground voltage indicated in
the table above, even though a neutral or ground wire is not physically present at the load.
The transformer is the best place to determine the circuit connection type because this is a
location where the voltage reference to ground can be conclusively identified.
1.1.2
Delta Connection
Delta connected services may be fed with either three wires or four wires. In a three-phase
delta service the load windings are connected from phase-to-phase rather than from
phase-to-ground. The following figure shows the physical load connections for a delta
service.
1–3
Ia
A
Iab
Vab
Vca
Ib
B
Vbc
Ica
Ibc
Ic
C
FIGURE 1–3: Three-phase Delta Winding Relationship
In this example of a delta service, three wires will transmit the power to the load. In a true
delta service, the phase-to-ground voltage will usually not be balanced because the
ground is not at the center of the delta.
The following diagram shows the phasor relationships between voltage and current on a
three-phase delta circuit.
In many delta services, one corner of the delta is grounded. This means the phase to
ground voltage will be zero for one phase and will be full phase-to-phase voltage for the
other two phases. This is done for protective purposes.
Vca
Ic
Vbc
Ia
Ib
Vab
FIGURE 1–4: Three-Phase Voltage and Current Phasors for Delta Winding
Another common delta connection is the four-wire, grounded delta used for lighting loads.
In this connection the center point of one winding is grounded. On a 120/240 volt, fourwire, grounded delta service the phase-to-ground voltage would be 120 volts on two
phases and 208 volts on the third phase. The phasor diagram for the voltages in a threephase, four-wire delta system is shown below.
1–4
Vnc
120 V
Vca
Vbc
120 V
Vbn
Vab
FIGURE 1–5: Three-Phase, Four-Wire Delta Phasors
1.1.3
Blondell’s Theorem and Three Phase Measurement
In 1893 an engineer and mathematician named Andre E. Blondell set forth the first
scientific basis for poly phase metering. His theorem states:
•
If energy is supplied to any system of conductors through N wires, the total power in the
system is given by the algebraic sum of the readings of N wattmeters so arranged that
each of the N wires contains one current coil, the corresponding potential coil being
connected between that wire and some common point. If this common point is on one
of the N wires, the measurement may be made by the use of N-1 wattmeters.
The theorem may be stated more simply, in modern language:
• In a system of N conductors, N-1 meter elements will measure the power or energy
taken provided that all the potential coils have a common tie to the conductor in
which there is no current coil.
• Three-phase power measurement is accomplished by measuring the three
individual phases and adding them together to obtain the total three phase value. In
older analog meters, this measurement was accomplished using up to three
separate elements. Each element combined the single-phase voltage and current to
produce a torque on the meter disk. All three elements were arranged around the
disk so that the disk was subjected to the combined torque of the three elements. As
a result the disk would turn at a higher speed and register power supplied by each
of the three wires.
According to Blondell's Theorem, it was possible to reduce the number of elements under
certain conditions. For example, a three-phase, three-wire delta system could be correctly
measured with two elements (two potential coils and two current coils) if the potential coils
were connected between the three phases with one phase in common.
In a three-phase, four-wire wye system it is necessary to use three elements. Three voltage
coils are connected between the three phases and the common neutral conductor. A
current coil is required in each of the three phases.
1–5
In modern digital meters, Blondell's Theorem is still applied to obtain proper metering. The
difference in modern meters is that the digital meter measures each phase voltage and
current and calculates the single-phase power for each phase. The meter then sums the
three phase powers to a single three-phase reading.
Some digital meters calculate the individual phase power values one phase at a time. This
means the meter samples the voltage and current on one phase and calculates a power
value. Then it samples the second phase and calculates the power for the second phase.
Finally, it samples the third phase and calculates that phase power. After sampling all three
phases, the meter combines the three readings to create the equivalent three-phase
power value. Using mathematical averaging techniques, this method can derive a quite
accurate measurement of three-phase power.
More advanced meters actually sample all three phases of voltage and current
simultaneously and calculate the individual phase and three-phase power values. The
advantage of simultaneous sampling is the reduction of error introduced due to the
difference in time when the samples were taken.
Blondell's Theorem is a derivation that results from Kirchhoff's Law. Kirchhoff's Law states
that the sum of the currents into a node is zero. Another way of stating the same thing is
that the current into a node (connection point) must equal the current out of the node. The
law can be applied to measuring three-phase loads. Figure 1.6 shows a typical connection
of a three-phase load applied to a three-phase, four-wire service. Krichhoff's Laws hold
that the sum of currents A, B, C and N must equal zero or that the sum of currents into
Node "n" must equal zero.
C
B
Phase B
Phase C
Node "n"
Phase A
A
N
FIGURE 1–6: Three-Phase Load Illustrating Kirchhoff’s Law and Blondell’s Theorem
If we measure the currents in wires A, B and C, we then know the current in wire N by
Kirchhoff's Law and it is not necessary to measure it. This fact leads us to the conclusion of
Blondell's Theorem that we only need to measure the power in three of the four wires if
they are connected by a common node. In the circuit of Figure 1.6 we must measure the
1–6
power flow in three wires. This will require three voltage coils and three current coils (a
three element meter). Similar figures and conclusions could be reached for other circuit
configurations involving delta-connected loads.
1–7
1.2
Power, Energy and Demand
It is quite common to exchange power, energy and demand without differentiating
between the three. Because this practice can lead to confusion, the differences between
these three measurements will be discussed.
Power is an instantaneous reading. The power reading provided by a meter is the present
flow of watts. Power is measured immediately just like current. In many digital meters, the
power value is actually measured and calculated over a one second interval because it
takes some amount of time to calculate the RMS values of voltage and current. But this
time interval is kept small to preserve the instantaneous nature of power.
Energy is always based on some time increment; it is the integration of power over a
defined time increment. Energy is an important value because almost all electric bills are
based, in part, on the amount of energy used.
Typically, electrical energy is measured in units of kilowatt-hours (kWh). A kilowatt-hour
represents a constant load of one thousand watts (one kilowatt) for one hour. Stated
another way, if the power delivered (instantaneous watts) is measured as 1,000 watts and
the load was served for a one hour time interval then the load would have absorbed one
kilowatt-hour of energy. A different load may have a constant power requirement of 4,000
watts. If the load were served for one hour it would absorb four kWh. If the load were
served for 15 minutes it would absorb ¼ of that total or 1 kWh.
The following figure shows a graph of power and the resulting energy that would be
transmitted as a result of the illustrated power values. For this illustration, it is assumed
that the power level is held constant for each minute when a measurement is taken. Each
bar in the graph will represent the power load for the one-minute increment of time. In real
life the power value moves almost constantly.
80
70
kilowatts
60
50
40
30
20
10
0
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
Time (minutes)
FIGURE 1–7: Power Use Over Time
1–8
The data from Figure 1-7 is reproduced in the table below to illustrate the calculation of
energy. Since the time increment of the measurement is one minute and since we
specified that the load is constant over that minute, we can convert the power reading to
an equivalent consumed energy reading by multiplying the power reading times 1/60
(converting the time base from minutes to hours).
Table 1–2: Power and Energy Relationship Over Time
Time Interval
(Minutes)
Power
(kW)
Energy
(kWh)
Accumulated
Energy (kWh)
1
30
0.50
0.50
2
50
0.83
1.33
3
40
0.67
2.00
4
55
0.92
2.92
5
60
1.00
3.92
6
60
1.00
4.92
7
70
1.17
6.09
8
70
1.17
7.26
9
60
1.00
8.26
10
70
1.17
9.43
11
80
1.33
10.76
12
50
0.83
12.42
13
50
0.83
12.42
14
70
1.17
13.59
15
80
1.33
14.92
As in Table 1-2, the accumulated energy for the power load profile of Figure 1-7 is 14.92
kWh.
Demand is also a time-based value. The demand is the average rate of energy use over
time. The actual label for demand is kilowatt-hours/hour but this is normally reduced to
kilowatts. This makes it easy to confuse demand with power. But demand is not an
instantaneous value. To calculate demand it is necessary to accumulate the energy
readings (as illustrated in Figure 1.7) and adjust the energy reading to an hourly value that
constitutes the demand.
In the example, the accumulated energy is 14.92 kWh. But this measurement was made
over a 15-minute interval. To convert the reading to a demand value, it must be
normalized to a 60-minute interval. If the pattern were repeated for an additional three 15minute intervals the total energy would be four times the measured value or 59.68 kWh.
The same process is applied to calculate the 15-minute demand value. The demand value
associated with the example load is 59.68 kWh/hr or 59.68 kWd. Note that the peak
instantaneous value of power is 80 kW, significantly more than the demand value.
1–9
Figure 1.8 shows another example of energy and demand. In this case, each bar
represents the energy consumed in a 15-minute interval. The energy use in each interval
typically falls between 50 and 70 kWh. However, during two intervals the energy rises
sharply and peaks at 100 kWh in interval number 7. This peak of usage will result in setting
a high demand reading. For each interval shown the demand value would be four times
the indicated energy reading. So interval 1 would have an associated demand of 240 kWh/
hr. Interval 7 will have a demand value of 400 kWh/hr. In the data shown, this is the peak
demand value and would be the number that would set the demand charge on the utility
bill.
As can be seen from this example, it is important to recognize the relationships between
power, energy and demand in order to control loads effectively or to monitor use correctly.
1.2.1
Demand
Demand is also a time-based value. The demand is the average rate of energy use over
time. The actual label for demand is kilowatt-hours/hour but this is normally reduced to
kilowatts. This makes it easy to confuse demand with power. But demand is not an
instantaneous value. To calculate demand it is necessary to accumulate the energy
readings and adjust the energy reading to an hourly value that constitutes the demand.
In the example, the accumulated energy is 14.92 kWh. But this measurement was made
over a 15-minute interval. To convert the reading to a demand value, it must be
normalized to a 60-minute interval. If the pattern were repeated for an additional three 15minute intervals the total energy would be four times the measured value or 59.68 kWh.
The same process is applied to calculate the 15-minute demand value. The demand value
associated with the example load is 59.68 kWh/hour or 59.68 kWd. Note that the peak
instantaneous value of power is 80 kW, significantly more than the demand value.
The following figure illustrates another example of energy and demand. In this case, each
bar represents the energy consumed in a 15-minute interval. The energy use in each
interval typically falls between 50 and 70 kWh. However, during two intervals the energy
rises sharply and peaks at 100 kWh in interval #7. This peak of usage will result in setting a
high demand reading. For each interval shown the demand value would be four times the
indicated energy reading. So interval 1 would have an associated demand of 240 kWh/hr.
Interval #7 will have a demand value of 400 kWh/hr. In the data shown, this is the peak
demand value and would be the number that would set the demand charge on the utility
bill.
1–10
100
kilowatt-hours
80
60
40
20
0
1
2
3
4
5
6
Intervals (15 mins.)
7
8
FIGURE 1–8: Energy Use and Demand Intervals
As seen in this example, it is important to recognize the relationships between power,
energy and demand in order to effectively control loads or to correctly monitor use.
1–11
1.3
Reactive Energy and Power Factor
1.3.1
Real, Reactive, and Apparent Power
The real power and energy measurements discussed in the previous section relate to the
quantities that are most used in electrical systems. But it is often not sufficient to only
measure real power and energy. Reactive power is a critical component of the total power
picture because almost all real-life applications have an impact on reactive power.
Reactive power and power factor concepts relate to both load and generation
applications. However, this discussion will be limited to analysis of reactive power and
power factor as they relate to loads. To simplify the discussion, generation will not be
considered.
Real power (and energy) is the component of power that is the combination of the voltage
and the value of corresponding current that is directly in phase with the voltage. However,
in actual practice the total current is almost never in phase with the voltage. Since the
current is not in phase with the voltage, it is necessary to consider both the inphase
component and the component that is at quadrature (angularly rotated 90o or
perpendicular) to the voltage. Figure 1.9 shows a single-phase voltage and current and
breaks the current into its in-phase and quadrature components.
IR
IX
V
I
FIGURE 1–9: Voltage and Complex Current
The voltage (V) and the total current (I) can be combined to calculate the apparent power
or VA. The voltage and the in-phase current (IR) are combined to produce the real power or
watts. The voltage and the quadrature current (IX) are combined to calculate the reactive
power.
The quadrature current may be lagging the voltage (as shown in Figure 1.9) or it may lead
the voltage. When the quadrature current lags the voltage the load is requiring both real
power (watts) and reactive power (VARs). When the quadrature current leads the voltage
the load is requiring real power (watts) but is delivering reactive power (VARs) back into the
system; that is VARs are flowing in the opposite direction of the real power flow.
Reactive power (VARs) is required in all power systems. Any equipment that uses
magnetization to operate requires VARs. Usually the magnitude of VARs is relatively low
compared to the real power quantities. Utilities have an interest in maintaining VAR
requirements at the customer to a low value in order to maximize the return on plant
invested to deliver energy. When lines are carrying VARs, they cannot carry as many watts.
1–12
So keeping the VAR content low allows a line to carry its full capacity of watts. In order to
encourage customers to keep VAR requirements low, most utilities impose a penalty if the
VAR content of the load rises above a specified value.
1.3.2
Power Factor
A common method of measuring reactive power requirements is power factor. Power
factor can be defined in two different ways. The more common method of calculating
power factor is the ratio of the real power to the apparent power. This relationship is
expressed in the following formula:
:
real power
watts
Total PF = ---------------------------------------- = -------------apparent power
VA
(EQ 1.1)
This formula calculates a power factor quantity known as Total Power Factor. It is called
Total PF because it is based on the ratios of the power delivered. The delivered power
quantities will include the impacts of any existing harmonic content. If the voltage or
current includes high levels of harmonic distortion the power values will be affected. By
calculating power factor from the power values, the power factor will include the impact of
harmonic distortion. In many cases this is the preferred method of calculation because the
entire impact of the actual voltage and current are included.
A second type of power factor is Displacement Power Factor. Displacement PF is based on
the angular relationship between the voltage and current. Displacement power factor
does not consider the magnitudes of voltage, current or power. It is solely based on the
phase angle differences. As a result, it does not include the impact of harmonic distortion.
Displacement power factor is calculated using the following equation:
Displacement PF = cos θ
(EQ 1.2)
Where θ is the angle between the voltage and the current (see Fig. 1.9).
In applications where the voltage and current are not distorted, the Total Power Factor will
equal the Displacement Power Factor. But if harmonic distortion is present, the two power
factors will not be equal.
1–13
1.4
Harmonic Distortion
Harmonic distortion is primarily the result of high concentrations of non-linear loads.
Devices such as computer power supplies, variable speed drives and fluorescent light
ballasts make current demands that do not match the sinusoidal waveform of AC
electricity. As a result, the current waveform feeding these loads is periodic but not
sinusoidal. Figure 1-10 shows a normal, sinusoidal current waveform. This example has no
distortion.
Current (amps)
1000
500
0
a
t
2a
–500
–1000
FIGURE 1–10: Non-distorted current waveform
Figure 1-11 shows a current waveform with a slight amount of harmonic distortion. The
waveform is still periodic and is fluctuating at the normal 60 Hz frequency. However, the
waveform is not a smooth sinusoidal form as seen in Figure 1-10.
1500
Current (amps)
1000
500
0
a
t
2a
–500
–1000
–1500
FIGURE 1–11: Distorted current wave
The distortion observed in Figure 1.11 can be modeled as the sum of several sinusoidal
waveforms of frequencies that are multiples of the fundamental 60 Hz frequency. This
modeling is performed by mathematically disassembling the distorted waveform into a
1–14
collection of higher frequency waveforms. These higher frequency waveforms are referred
to as harmonics. Figure 1.12 shows the content of the harmonic frequencies that make up
the distortion portion of the waveform in Figure 1-11.
250
200
Current (amps)
150
100
50
t
0
a
-50
-100
-150
-200
-250
FIGURE 1–12: Waveforms of the harmonics
The waveforms shown in Figure 1-12 are not smoothed but do provide an indication of the
impact of combining multiple harmonic frequencies together.
When harmonics are present it is important to remember that these quantities are
operating at higher frequencies. Therefore, they do not always respond in the same
manner as 60 Hz values.
1.4.1
Inductive and capacitive impedance
Inductive and capacitive impedance are present in all power systems. We are accustomed
to thinking about these impedances as they perform at 60 Hz. However, these impedances
are subject to frequency variation.
X L = jωL and X C = 1 ⁄ jωC
(EQ 1.3)
At 60 Hz, ω = 377; but at 300 Hz (5th harmonic) ω = 1,885. As frequency changes
impedance changes and system impedance characteristics that are normal at 60 Hz may
behave entirely different in presence of higher order harmonic waveforms.
Traditionally, the most common harmonics have been the low order, odd frequencies, such
as the 3rd, 5th, 7th, and 9th. However newer, non-linear loads are introducing significant
quantities of higher order harmonics.
1.4.2
Voltage and Current Monitoring
Since much voltage monitoring and almost all current monitoring is performed using
instrument transformers, the higher order harmonics are often not visible. Instrument
transformers are designed to pass 60 Hz quantities with high accuracy. These devices,
when designed for accuracy at low frequency, do not pass high frequencies with high
1–15
accuracy; at frequencies above about 1200 Hz they pass almost no information. So when
instrument transformers are used, they effectively filter out higher frequency harmonic
distortion making it impossible to see.
However, when monitors can be connected directly to the measured circuit (such as direct
connection to 480 volt bus) the user may often see higher order harmonic distortion. An
important rule in any harmonics study is to evaluate the type of equipment and
connections before drawing a conclusion. Not being able to see harmonic distortion is not
the same as not having harmonic distortion.
1.4.3
Waveform Capture
It is common in advanced meters to perform a function commonly referred to as
waveform capture. Waveform capture is the ability of a meter to capture a present picture
of the voltage or current waveform for viewing and harmonic analysis. Typically a
waveform capture will be one or two cycles in duration and can be viewed as the actual
waveform, as a spectral view of the harmonic content, or a tabular view showing the
magnitude and phase shift of each harmonic value. Data collected with waveform capture
is typically not saved to memory. Waveform capture is a real-time data collection event.
Waveform capture should not be confused with waveform recording that is used to record
multiple cycles of all voltage and current waveforms in response to a transient condition.
1–16
1.5
Power Quality
Power quality can mean several different things. The terms ‘power quality’ and ‘power
quality problem’ have been applied to all types of conditions. A simple definition of ‘power
quality problem’ is any voltage, current or frequency deviation that results in mis-operation
or failure of customer equipment or systems. The causes of power quality problems vary
widely and may originate in the customer equipment, in an adjacent customer facility or
with the utility.
In his book “Power Quality Primer,” Barry Kennedy provided information on different types
of power quality problems. Some of that information is summarized in Table 1-3 below.
Table 1–3: Typical Power Quality Problems and Sources
Cause
Disturbance Type
Source(s)
Impulse transient
Transient voltage
disturbance, sub-cycle
duration
Lightning;
Electrostatic discharge;
Load switching;
Capacitor switching
Oscillatory transient with
decay
Transient voltage, sub-cycle
duration
Line/cable switching;
Capacitor switching;
Load switching
Sag/swell
RMS voltage, multiple cycle
duration
Remote system faults
Interruptions
RMS voltage, multiple second
or longer duration
System protection;
Circuit breakers;
Fuses;
Maintenance
Undervoltage/Overvoltage
RMS voltage, steady state,
multiple second or longer
duration
Motor starting;
Load variations;
Load dropping
Voltage flicker
RMS voltage, steady state,
repetitive condition
Intermittent loads;
Motor starting;
Arc furnaces
Harmonic distortion
Steady-state current or
voltage, long term duration
Non-linear loads;
System resonance
It is often assumed that power quality problems originate with the utility. While it is true
that may power quality problems can originate with the utility system, many problems
originate with customer equipment. Customer-caused problems may manifest themselves
inside the customer location or they may be transported by the utility system to another
adjacent customer. Often, equipment that is sensitive to power quality problems may in
fact also be the cause of the problem.
If a power quality problem is suspected, it is generally wise to consult a power quality
professional for assistance in defining the cause and possible solutions to the problem.
1–17
1–18
Digital Energy
Multilin
Metering System
Chapter 2: Overview and
Specifications
Overview and Specifications
2.1
Hardware Overview
The EPM2200 monitor is a 0.5% class electrical panel meter. Using bright and large .56”
LED displays, it is designed to be used in electrical panels and swtichgear. The meter has a
unique anti-dither algorithm to improve reading stability. The EPM2200 meter uses highspeed DSP technology with high-resolution A/D conversion to provide stable and reliable
measurements.
The EPM2200 meter is a meter and transducer in one compact unit. Featuring an optional
RS485 port, it can be programmed using the faceplate of the meter or through software.
ANSI or DIN mounting may be used..
EPM2200 meter features that are detailed in this manual are as follows:
2.1.1
•
0.5% Class Accuracy
•
Multifunction Measurement including Voltage, Current, Power, Frequency, Energy, etc.
•
Percentage of Load Bar for Analog Meter Perception
•
Easy to Use Faceplate Programming
•
RS485 Modbus Communication
Voltage and Current Inputs
Universal Voltage Inputs
Voltage Inputs allow measurement to 416 Volts Line-to-Neutral and 721 Volts Line-to-Line.
This insures proper meter safety when wiring directly to high voltage systems. One unit will
perform to specification on 69 Volt, 120 Volt, 230 Volt, 277 Volt, 277 Volt and 347 Volt
power systems.
Current Inputs
The EPM2200 meter’s Current Inputs use a unique dual input method:
Method 1: CT Pass Through.
2–1
CHAPTER 2: OVERVIEW AND SPECIFICATIONS
The CT passes directly through the meter without any physical termination on the meter.
This insures that the meter cannot be a point of failure on the CT circuit. This is preferable
for utility users when sharing relay class CTs. No Burden is added to the secondary CT
circuit.
Method 2: Current “Gills”.
This unit additionally provides ultra-rugged Termination Pass Through Bars that allow CT
leads to be terminated on the meter. This, too, eliminates any possible point of failure at
the meter. This is a preferred technique for insuring that relay class CT integrity is not
compromised (the CT will not open in a fault condition).
2.1.2
Order Codes
The order codes for the EPM 2200 are indicated below.
Table 2–1: EPM 2200 Order Codes
PL2200
–
Option
*
A1
B1
C1
Communications
–
*
|
|
|
X
S
Volts and Amps Meter
Volts, Amps, Power & Frequency
Volts, Amps, Power, Frequency & Energy Counters
None
RS485 + Pulse
For example, to order an EPM 2200 to measure Volts, Amps, Power & Frequency, with RS485
+ Pulse communications, use PL2200-B-S.
2.1.3
Measured Values
The following table lists the measured values available in real time, average, maximum,
and minimum.
Table 2–2: EPM 2200 Measured Values
Measured Values
2–2
Real Time
Average
Maximum
Minimum
Voltage L-N
X
X
X
Voltage L-L
X
X
X
Current per phase
X
X
X
X
Current Neutral
X
Watts
X
X
X
X
VARs
X
X
X
X
VA
X
X
X
X
Power Factor (PF)
X
X
X
X
Positive watt-hours
X
Table 2–2: EPM 2200 Measured Values
Measured Values
2.1.4
Real Time
Negative watt-hours
X
Net watt-hours
X
Positive VAR-hours
X
Negative VAR-hours
X
Net VAR-hours
X
VA-hours
X
Frequency
X
Voltage angles
X
Current angles
X
% of load bar
X
Average
Maximum
Minimum
X
X
Utility Peak Demand
The EPM 2200 provides user-configured Block (fixed) window, or Rolling window demand.
This feature allows you to set up a customized demand profile. Block window demand is
demand used over a user-configured demand period (usually 5, 15, or 30 minutes). Rolling
window demand is a fixed window demand that moves for a user-specified subinterval
period. For example, a 15-minute demand using 3 subintervals and providing a new
demand reading every 5 minutes, based on the last 15 minutes.
Utility demand features can be used to calculate kW, kVAR, kVA and PF readings. All other
parameters offer maximum and minimum capability over the user-selectable averaging
period. Voltage provides an instantaneous maximum and minimum reading which
displays the highest surge and lowest sag seen by the meter.
2–3
2.2
Specifications
POWER SUPPLY
Range:..................................................................Universal, (90 to 265) VAC @50/60Hz
Power consumption:.....................................5 VA
VOLTAGE INPUTS (MEASUREMENT CATEGORY III)
Range:..................................................................Universal, Auto-ranging up to 416 V AC L-N, 721 V AC L-L
Supported hookups:......................................3-element Wye, 2.5-element Wye, 2-element Delta,
4-wire Delta
Input impedance: ...........................................1 MOhm/phase
Burden: ................................................................0.0144 VA/phase at 120 Volts
Pickup voltage: ................................................10 V AC
Connection: .......................................................Screw terminal
Maximum input wire gauge: ....................AWG #12 / 2.5 mm2
Fault withstand: ..............................................Meets IEEE C37.90.1
Reading:..............................................................Programmable full-scale to any PT ratio
CURRENT INPUTS
Class 10:..............................................................5 A nominal, 10 A maximum
Burden: ................................................................0.005 VA per phase maximum at 11 A
Pickup current:.................................................0.1% of nominal
Connections:.....................................................O or U lug;
Pass-through wire, 0.177" / 4.5 mm maximum diameter
Quick connect, 0.25" male tab
Fault Withstand (at 23°C):...........................100 A / 10 seconds, 300 A / 3 seconds, 500 A / 1 second
Reading:..............................................................Programmable full-scale to any CT ratio
MEASUREMENT METHODS
Voltage and current: .....................................True RMS
Power:..................................................................Sampling at 400+ samples/cycle on all channels
measured; readings simultaneously
A/D conversion:...............................................6 simultaneous 24-bit analog-to-digital converters
UPDATE RATE
All parameters: ................................................Up to 1 second
ACCURACY
For 230 C, 3 Phase balanced Wye or Delta load.
Parameter
Voltage L-N [V]
Voltage L-L [V}
Current Phase [A]
Current Neutral (calculated) [A]
Active Power Total [W]
Active Energy Total [Wh]
Reactive Power Total [VAR]
Reactive Energy Total [VARh]
Apparent Power Total [VA]
Apparent Energy Total [VAh]
Power Factor
Frequency
Load Bar
2–4
Accuracy
0.2% of reading2
0.4% of reading
0.2% of reading1
2% of Full Scale1
0.5% of reading1,2
0.5% of reading1,2
1.0% of reading1,2
1.0% of reading1,2
1.0% of reading1,2
1.0% of reading1,2
1.0% of reading1,2
+/- 0.01Hz
+/- 1 segment
Accuracy Input Range
(69 to 480)V
(120 to 600)V
(0.15 to 5)A
(0.15 to 5)A @ (45 to 65)Hz
(0.15 to 5)A @ (69 to 480)V @ +/- (0.5 to 1) lag/lead PF
(0.15 to 5)A @ (69 to 480)V @ +/- (0 to 0.8) lag/lead PF
(0.15 to 5)A @ (69 to 480)V @ +/- (0 to 0.8) lag/lead PF
(45 to 65)Hz
(0.005 to 6)A
1 For 2.5 element programmed units, degrade accuracy by an additional 0.5% of reading.
2 For unbalanced voltage inputs where at least one crosses the 150V auto-scale threshold
(for example, 120V/120V/208V system), degrade accuracy by additional 0.4%.
EPM 2200 accuracy meets the IEC62053-22 Accuracy Standards for 0.5% Class Meters.
This standard is shown in the table below.
Note
Value of Current
Power Factor
Percentage Error Limits for
Meters of Class 0.5 S
0.01 In ≤ I < 0. 05 In
1
±1.0
0.05 In ≤ I ≤ Imax
1
±0.5
0.02 In ≤ I < 0.1 In
0.5 inductive
0.8 capacitive
±1.0
±1.0
0.1 In ≤ I ≤ Imax
0.5 inductive
0.8 capacitive
±0.6
±0.6
When specially requested by
the user, from:
0.1 In ≤ I ≤ Imax
0.25 inductive
0.8 capacitive
±1.0
±1.0
In the table above:
In = Nominal (5A)
Imax = Full Scale
ISOLATION
All Inputs and Outputs are galvanically isolated to 2500 V AC
ENVIRONMENTAL
Storage:...............................................................–20 to 70°C
Operating:..........................................................-10 to 60°C
Humidity:............................................................up to 95% RH, non-condensing
Faceplate rating: ............................................NEMA 12 (water resistant), mounting gasket included
COMMUNICATIONS FORMAT
Types:...................................................................RS485P - RS485 port through back plate plus KYZ Pulse
KYZ/RS485 PORT SPECIFICATIONS
RS485 Transceiver; meets or exceeds EIA/TIA-485 Standard:
Type: ....................................................................Two-wire, half duplex
Min. Input Impedance: ................................96kΩ
Max. Output Current: ...................................±60mA
Wh PULSE
KYZ output contacts (and infrared LED light pulses through face plate):
Pulse Width: .....................................................40ms
Full Scale Frequency: ...................................6Hz
Contact type: ...................................................Solid State – SPDT (NO – C – NC)
Relay type: ........................................................Solid state
Peak switching voltage: .............................DC ±350V
Continuous load current: ...........................120mA
Peak load current: .........................................350mA for 10ms
On resistance, max.: ....................................35Ω
Leakage current: ...........................................1μA@350V
Isolation: ............................................................AC 3750V
Reset State: ......................................................(NC - C) Closed; (NO - C) Open
2–5
Infrared LED:
Peak Spectral Wavelength: ......................940nm
Reset State: ......................................................Off
FIGURE 2–1: Internal Schematic (De-energized State)
FIGURE 2–2: Output Timing
2–6
COMMUNICATIONS PORTS
Protocols: ...........................................................Modbus RTU, Modbus ASCII
Baud rate: ..........................................................9600 to 57600 bps
Port address: ....................................................001 to 247
Data format: .....................................................8 bits, no parity
MECHANICAL PARAMETERS
Dimensions: ......................................................4.25" × 4.82" × 4.85" (L × W × H)
105.4 mm × 123.2 mm × 123.2 mm (L × W × H)
Mounting: ...........................................................mounts in 92 mm square DIN or ANSI C39.1, 4-inch round
cut-out
Weight: ................................................................2 pounds / 0.907 kg
COMPLIANCE
Test
Reference Standard
IEC62053-22 (0.5% Accuracy)
ANSI C12.20 (0.5% Accuracy)
Surge Withstand
ANSI (IEEE) C37.90
Burst
ANSI C62.41
Electrostatic Discharge
IEC1000-4-2
RF Immunity
EC1000-4-3
Fast Transient
IEC1000-4-4
Surge Immunity
IEC1000-4-5
APPROVALS
Applicable Council Directive
North America
UL Recognized
ISO
Manufactured under a registered
quality program
According to:
UL61010-1
C22.2. No 61010-1 (PICQ7)
ISO9001
2–7
2–8
Digital Energy
Multilin
Metering System
Chapter 3: Mechanical Installation
Mechanical Installation
3.1
Introduction
The EPM2200 meter can be installed using a standard ANSI C39.1 (4" Round) or an IEC
92mm DIN (Square) form. In new installations, simply use existing DIN or ANSI punches.
For existing panels, pull out old analog meters and replace with the EPM2200 meter. The
various models use the same installation. See Chapter 4 for wiring diagrams.
3–1
CHAPTER 3: MECHANICAL INSTALLATION
ANSI Mounting
Rods (screw-in)
DIN
Mounting
Brackets
FIGURE 3–1: EPM2200 Mounting Information
Recommended Tools for EPM2200 Meter Installation:
3–2
•
#2 Phillips screwdriver, small wrench and wire cutters.
•
Mount the meter in a dry location free from dirt and corrosive substances. The meter
is designed to withstand harsh environmental conditions. (See Environmental
Specifications in Chapter 2.)
3.2
ANSI Installation Steps
1.
Insert 4 threaded rods by hand into the back of meter. Twist until secure.
2.
Slide ANSI 12 Mounting Gasket onto back of meter with rods in place.
3.
Slide meter into panel.
4.
Secure from back of panel with lock washer and nut on each threaded rod.
Use a small wrench to tighten. Do not overtighten. The maximum installation
torque is 0.4 Newton-Meter.
NEMA12 mounting
gasket
threaded rods
lock washer
and nut
FIGURE 3–2: ANSI Mounting Procedure
3–3
3.3
DIN Installation Steps
1.
Slide meter with NEMA 12 Mounting Gasket into panel. (Remove ANSI Studs, if
in place.)
2.
From back of panel, slide 2 DIN Mounting Brackets into grooves in top and
bottom of meter housing. Snap into place.
3.
Secure meter to panel with lock washer and a #8 screw through each of the 2
mounting brackets. Tighten with a #2 Phillips screwdriver. Do not overtighten.
The maximum installation torque is 0.4 Newton-Meter.
DIN mounting
bracket
top-mounting
bracket groove
bottom mounting
bracket groove
#8 screw
EPM 2200 meter
with NEMA 12
mounting gasket
Remove (unscrew)
ANSI studs for DIN
Installation
FIGURE 3–3: DIN Mounting Procedure
3–4
Digital Energy
Multilin
Metering System
Chapter 4: Electrical Installation
Electrical Installation
4.1
Considerations When Installing Meters
•
Installation of the EPM2200 Meter must be performed by only qualified personnel who
follow standard safety precautions during all procedures. Those personnel should
have appropriate training and experience with high voltage devices. Appropriate
safety gloves, safety glasses and protective clothing is recommended.
•
During normal operation of the EPM2200 Meter, dangerous voltages flow through
many parts of the meter, including: Terminals and any connected CTs (Current
Transformers) and PTs (Potential Transformers), all I/O Modules (Inputs and Outputs)
and their circuits. All Primary and Secondary circuits can, at times, produce lethal
voltages and currents. Avoid contact with any current-carrying surfaces.
•
Do not use the meter or any I/O Output Device for primary protection or in an energylimiting capacity. The meter can only be used as secondary protection. Do not use
the meter for applications where failure of the meter may cause harm or death. Do
not use the meter for any application where there may be a risk of fire.
•
All meter terminals should be inaccessible after installation.
•
Do not apply more than the maximum voltage the meter or any attached device can
withstand. Refer to meter and/or device labels and to the Specifications for all devices
before applying voltages. Do not HIPOT/Dielectric test any Outputs, Inputs or
Communications terminals.
•
GE recommends the use of Shorting Blocks and Fuses for voltage leads and power
supply to prevent hazardous voltage conditions or damage to CTs, if the meter needs
to be removed from service. CT grounding is optional.
If the equipment is used in a manner not specified by the manufacturer, the protection
provided by the equipment may be impaired.
4–1
CHAPTER 4: ELECTRICAL INSTALLATION
There is no required preventive maintenance or inspection necessary for safety.
however, any repair or maintenance should be performed by the factory.
Note
DISCONNECT DEVICE: The following part is considered the equipment disconnect
device:
A switch or circuit-breaker shall be included in the end-use equipment or building
installation. the switch shall be in close proximity to the equipment and within easy
reach of the operator. the switch shall be marked as the disconnecting device for the
equipment.
4.1.1
CT Leads Terminated to Meter
The EPM 2200 is designed to have Current Inputs wired in one of three ways. Figure 4–1:
below, shows the most typical connection where CT Leads are terminated to the meter at
the Current Gills.
This connection uses Nickel-Plated Brass Studs (Current Gills) with screws at each end. This
connection allows the CT wires to be terminated using either an “O” or a “U” lug. Tighten
the screws with a #2 Phillips screwdriver. The maximum installation torque is 1 NewtonMeter.
Other current connections are shown in Figures 3.6 and 3.7. A Voltage and RS-485
Connection is shown in Figure 3.8..
Current gills
(nickel-plated
brass stud)
FIGURE 4–1: CT leads terminated to meter, #8 screw for lug connection
4–2
Wiring diagrams are detailed in the diagrams shown below in this chapter.
Communications connections are detailed in Chapter 5.
4.1.2
CT Leads Pass-Through (No Meter Termination)
The second method allows the CT wires to pass through the CT Inputs without terminating
at the meter. In this case, remove the current gills and place the CT wire directly through
the CT opening. The opening will accommodate up to 0.177" / 4.5 mm maximum diameter
CT wire.
CT wire passing
through the meter
Current gills
removed
FIGURE 4–2: Pass-Through Wire Electrical Connection
4.1.3
Quick Connect Crimp CT Terminations
For quick termination or for portable applications, a quick connect crimp CT connection
can also be used.
4–3
Crimp CT
terminations
FIGURE 4–3: Quick Connect Electrical Connection
4.1.4
Voltage and Power Supply Connections
Voltage Inputs are connected to the back of the unit via a optional wire connectors. The
connectors accommodate up to AWG#12 / 2.5 mm wire.
4–4
Power supply
inputs
RS485 outputs
(do not place voltage
on these terminals!)
Voltage
inputs
FIGURE 4–4: Voltage Connection
4.1.5
Ground Connections
The EPM 2200 ground terminals (
) should be connected directly to the installation's
protective earth ground. Use 2.5 mm wire for this connection.
4.1.6
Voltage Fuses
GE Multilin recommends the use of fuses on each of the sense voltages and on the control
power, even though the wiring diagrams in this chapter do not show them.
• Use a 0.1 Amp fuse on each voltage input.
• Use a 3.0 Amp fuse on the Power Supply.
4–5
4.2
Electrical Connection Diagrams
4.2.1
Description
Choose the diagram that best suits your application and maintains the CT polarity.
1.
Three-phase, four-wire system Wye with no PTs (direct voltage), 3 CTs, 3
element.
1a. Dual Phase Hookup
1b. Single Phase Hookup
2.
Three-phase, four-wire system Wye with no PTs (direct voltage), 3 CTs, 2.5
element.
3.
Three-phase, four-wire Wye with 3 PTs, 3 CTs, 3 element.
4.
Three-phase, four-wire Wye with 2 PTs, 3 CTs, 2.5 element.
5.
Three-phase, three-wire Delta with no PTs (direct voltage), 2 CTs.
6.
Three-phase, three-wire Delta with 2 PTs, 2 CTs.
7.
Three-phase, three-wire Delta with 2 PTs, 3 CTs.
8.
Current-only measurement (three-phase).
9.
Current-only measurement (dual-phase).
10. Current-only measurement (single-phase).
These diagrams are indicated in the sections following.
4–6
4.2.2
(1) Wye, 4-Wire with no PTs and 3 CTs, no PTs, 3 Element
For this wiring type, select 3 EL WYE (3-element Wye) in the meter programming setup.
FIGURE 4–5: 4-Wire Wye with no PTs and 3 CTs, 3 Element
4–7
4.2.3
4–8
(1a) Dual Phase Hookup
4.2.4
(1b) Single Phase Hookup
4–9
4.2.5
(2) Wye, 4-Wire with no PTs and 3 CTs, 2.5 Element
For this wiring type, select 2.5EL WYE (2.5-element Wye) in the meter programming setup.
FIGURE 4–6: 4-Wire Wye with no PTs and 3 CTs, 2.5 Element
4–10
4.2.6
(3) Wye, 4-Wire with 3 PTs and 3 CTs, 3 Element
For this wiring type, select 3 EL WYE (3-element Wye) in the meter programming setup.
FIGURE 4–7: 4-Wire Wye with 3 PTs and 3 CTs, 3 Element
4–11
4.2.7
(4) Wye, 4-Wire with 2 PTs and 3 CTs, 2.5 Element
For this wiring type, select 2.5EL WYE (2.5-element Wye) in the meter programming setup.
FIGURE 4–8: 4-Wire Wye with 2 PTs and 3 CTs, 2.5 Element
4–12
4.2.8
(5) Delta, 3-Wire with no PTs, 2 CTs
For this wiring type, select 2 Ct dEL (2 CT Delta) in the meter programming setup.
FIGURE 4–9: 3-Wire Delta with no PTs and 2 CTs
4–13
4.2.9
(6) Delta, 3-Wire with 2 PTs, 2 CTs
FIGURE 4–10: 3-Wire Delta with 2 PTs and 2 CTs
4–14
4.2.10 (7) Delta, 3-Wire with 2 PTs, 3 CTs
FIGURE 4–11: 3-Wire Delta with 2 PTs and 3 CTs
4–15
4.2.11 (8) Current-Only Measurement (Three-Phase)
For this wiring type, select 3 EL WYE (3 Element Wye) in the meter programming setup.
FIGURE 4–12: Current-Only Measurement (Three-Phase)
Note
4–16
Even if the meter is used only for current measurement, the unit requires a AN volts
reference. Please ensure that the voltage input is attached to the meter. AC control power
can be used to provide the reference signal.
4.2.12 (9) Current-Only Measurement (Dual-Phase)
FIGURE 4–13: Current-Only Measurement (Dual-Phase)
Note
4–17
4.2.13 (10) Current-Only Measurement (Single-Phase)
FIGURE 4–14: Current-Only Measurement (Single-Phase)
Note
4–18
Digital Energy
Multilin
Metering System
Chapter 5: Communication
Installation
Communication Installation
5.1
EPM2200 Communication
Through the 485P option, the EPM 2200 meter provides RS485 communication speaking
Modbus ASCII and Modbus RTU protocols.
5.1.1
RS-485 / KYZ Output COM 2 (485P Option)
The 485P Option provides a combination RS485 and a KYZ Pulse Output for pulsing energy
values. The RS485 / KYZ Combo is located on the terminal section of the meter.
The EPM2200 meter’s RS485 port can be programmed with the buttons on the face of the
meter or by using GE Communicator EXT 3.0 software.
The standard RS485 Port Settings are as follows:
•
Address: 001 to 247
•
Baud Rate: 9600, 19200, 38400 or 57600
•
Protocol: Modbus RTU, Modbus ASCII
5–1
CHAPTER 5: COMMUNICATION INSTALLATION
FIGURE 5–1: 485P Option with RS-485 Communication Installation
RS485 allows you to connect one or multiple EPM2200 meters to a PC or other device, at
either a local or remote site. All RS485 connections are viable for up to 4000 feet (1219.20
meters).
FIGURE 5–2: EPM2200 Connected to PC via RS485
As shown in Figure 5-2, to connect a EPM2200 to a PC, you need to use an RS485 to RS232
converter.
Figure 5-3 below, shows the detail of a 2-wire RS485 connection.
5–2
EPM2200 Meter
RS485 Connection
From other RS-485 device:
-
- Connect (-) to (-)
+
- Connect (+) to (+)
- Connect Shield (SH)
to Shield (SH)
SH
+
SH
Twisted Pair, Shielded Cable
FIGURE 5–3: 2-wire RS485 Connection
Note
For All RS485 Connections:
•
Use a shielded twisted pair cable 22 AWG (0.33 mm2) or larger, grounding the shield at
one end only.
•
Establish point-to-point configurations for each device on a RS485 bus: connect ’+’
terminals to ’+’ terminals; connect ’-’ terminals to ’-’ terminals.
•
You may connect up to 31 meters on a single bus using RS485. Before assembling the
bus, each meter must be assigned a unique address: refer to Chapter 5 of the GE
Communicator EXT User’s Manual for instructions.
•
Protect cables from sources of electrical noise.
•
Avoid both “Star” and “Tee” connections (see Figure 5.7).
•
No more than two cables should be connected at any one point on an RS485 network,
whether the connections are for devices, converters, or terminal strips.
•
Include all segments when calculating the total cable length of a network. If you are
not using an RS485 repeater, the maximum length for cable connecting all devices is
4000 feet (1219.20 meters).
•
Connect shield to RS485 Master and individual devices as shown in Figure 5.6. You
may also connect the shield to earth-ground at one point.
•
Termination Resistors (RT) may be needed on both ends of longer length transmission
lines. However, since the meter has some level of termination internally, Termination
Resistors may not be needed. When they are used, the value of the Termination
Resistors is determined by the electrical parameters of the cable.
Figure 5-4 shows a representation of an RS485 Daisy Chain connection.
5–3
FIGURE 5–4: RS485 Daisy Chain Connection
FIGURE 5–5: Incorrect “T” and “Star” Topologies
5–4
5.2
EPM2200 Communication and Programming Overview
The EPM2200 meter can be programmed either through the buttons on the faceplate or
through software. Software programming and communication utilize the RS485
connection on the back of the meter, as shown in fig 5-3. Once a connection is established,
GE Communicator EXT 3.0 software can be used both to program the meter and to
communicate with EPM2200 slave devices.
Meter Connection
To provide power to the meter, use one of the wiring diagrams in Chapter 4 or attach an
Aux cable to GND, L(’+’) and N(’-’).
The RS-485 cable attaches to SH, ’-’ and ’+’ as shown above.
5.2.1
Factory Initial Default Settings
You can connect to the EPM2200 using the Factory Initial Default Settings. This feature is
useful in debugging or in any situtation where you do not know the meter’s programmed
settings and want to find them.
When the EPM2200 is powered up, you have up to 5 seconds to poll the Name Register as
shown in the example below: “How to Connect.” You will be connected to the meter with
the Factory Initial Default Settings. The meter continues to operate with these default
settings for 5 minutes. During this time, you can access the meter’s Device Profile to
ascertain/change meter information. After the 5 minutes have passed, the meter reverts
to the programmed Device Profile settings.
Note
Factory Initial Default Settings:
•
Baud Rate: 9600
•
Port: COM1
•
Protocol: Modbus RTU
How to Connect
1.
Open GE Communicator EXT software.
2.
Click the Connect button on the tool bar.
FIGURE 5–6: Connect Button
The Connect screen appears, showing the Default settings. Make sure your settings are the
same as shown here. Use the pull-down windows to make changes, if necessary.
5–5
FIGURE 5–7: Serial Port settings
3.
Note
Click the Connect button on the screen.
If you do not connect with the Factory Initial Default Settings within 5 seconds after
powering on the meter, the Device Profile reverts to the programmed Device Profile. In that
case, disconnect and reconnect power before clicking the Connect button.
The Device Status screen appears, confirming a connection.
FIGURE 5–8: Device Status screen
Click OK. The main screen of GE Communicator EXT software reappears.
5–6
4.
Click the Profile icon on the left of the toolbar. A set of EPM2200 Profile Programming
Screens appears:
5.
Click the Communication tab. The Communication Settings appear.
Use drop-down menus to change settings, if desired.
5–7
Communication Settings
•
COM2 (RS485)
•
Address (1-247)
•
Protocol (Modbus RTU, ASCII)
•
Baud Rate (9600 to 57600)
•
Response Delay (0-750 msec)
COM1 is not used by the EPM2200 meter.
Note
5.2.2
6.
When changes are complete, click the Update button to send a new profile to the
meter.
7.
Click Cancel to Exit the Profile (or)
8.
Click other tabs to update other aspects of the Profile (see section 5.2.2 below).
Additional EPM2200 Profile Settings
SCALING (CT, PT Ratios and System Wiring)
5–8
•
CT Numerator (Primary):
•
CT Denominator (Secondary): 5 (factory set)
•
CT Multiplier:
•
CT Fullscale: Calculation Based on Selections
•
PT Numerator (Primary):
•
PT Denominator (Secondary):
•
PT Multiplier:
•
PT Fullscale: Calculation Based on Selections
System Wiring: Number of Phases: One, Two or Three
Note
VOLTS FULL SCALE = PT Numerator x PT Multiplier
You must specify Primary and Secondary Voltage in Full Scale. Do not use ratios! The PT
Denominator should be the Secondary Voltage level.
Example:
A 14400/120 PT would be entered as:
PT Num: 1440
PT Denom: 120
Multiplier: 10
This example would display a 14.40kV.
Example CT Settings:
200/5 Amps: Set the Ct-n value for 200, Ct-Multiplier value for 1.
800/5 Amps: Set the Ct-n value for 800, Ct-Multiplier value for 1.
2,000/5 Amps: Set the Ct-n value for 2000, Ct-Multiplier value for 1.
10,000/5 Amps: Set the Ct-n value for 1000, Ct-Multiplier value for 10.
Example PT Settings:
277/277 Volts Pt-n value is 277, Pt-d value is 277, Pt-Multiplier is 1.
14,400/120 Volts: Pt-n value is 1440, Pt-d value is 120, Pt-Multiplier value is 10.
138,000/69 Volts: Pt-n value is 1380, Pt-d value is 69, Pt-Multipier value is 100.
345,000/115 Volts: Pt-n value is 3470, Pt-d value is 115, Pt-Multiplier value is 100
345,000/69 Volts: Pt-n value is 345, Pt-d value is 69, Pt-Multiplier value is 1000.
Note
Settings are the same for Wye and Delta configurations.
5–9
ENERGY AND DISPLAY POWER AND ENERGY FORMAT
Power Scale
Energy Digits
Energy Decimal Places
Energy Scale
(Example Based on Selections)
Power Direction: View as Load
Demand Averaging
Averaging Method: Block or Rolling
Interval (Minutes)
Sub Interval
Auto Scroll: Click to Activate
Display Configuration:
Click Values to be displayed.
Note
Note
5–10
You MUST have at lease ONE selected.
If incorrect values are entered on this screen the following message appears:
Current, CT, PT and Energy Settings will cause invalid energy accumulator values.
Change the inputted settings until the message disappears.
SETTINGS
Password (Meter is shipped with Password Disabled; there is NO DEFAULT PASSWORD)
Enable Password for Reset
Enable Password for Configuration
Change Password
Change VSwitch
(Call GE Multilin for Update Information.)
Change Device Designation
Enter a new Device label in the entry field.
1.
Click Update to send a new Profile.
After programming the Device Profile, click:
• Update to send the new Profile to the connected meter.
Note
If the Update fails, the software asks if you want to try again to Update.
• Save to save the Device Profile settings in a file.
• Cancel (once you have loaded or saved the Device Profile) to Exit the EPM2200
Profile screen.
5–11
If you click Cancel before Save or Update, you will lose any changes you have made to the
Device Profile.
2.
5–12
Use GE Communicator EXT to communicate with the device and perform required
tasks.Refer to the GE Communicator EXT User’s Manual for more details. You can
access the manual online by clicking Help > Contents from the GE Communicator EXT
Main screen.
Digital Energy
Multilin
Metering System
Chapter 6: Using the Meter
Using the Meter
6.1
Introduction
The EPM2200 meter can be configured and a variety of functions can be accomplished
simply by using the Elements and the Buttons on the meter face. This chapter will review
Front Panel Navigation. Complete Navigation Maps can be found in Appendix A of this
manual.
Parameter
designator
Reading
type indicator
% of Load Bar
Scale Selector
FIGURE 6–1: Faceplate of EPM2200 Meter with Elements
6.1.1
Meter Face Elements
• Reading Type Indicator:
Indicates Type of Reading
6–1
CHAPTER 6: USING THE METER
• % of Load Bar:
Graphic Display of Amps as % of the Load
• Parameter Designator:
Indicates Reading Displayed
• Scale Selector:
Kilo or Mega multiplier of Displayed Readings
ENTER
button
MENU
button
RIGHT
button
DOWN
button
FIGURE 6–2: EPM 2200 Faceplate Buttons
6.1.2
Meter Face Buttons
Using Menu, Enter, Down and Right Buttons, perform the following functions:
• View Meter Information
• Enter Display Modes
• Configure Parameters (Password Protected)
• Perform Resets
• Perform LED Checks
• Change Settings
• View Parameter Values
• Scroll Parameter Values
Enter Button: Press and release to enter one of four Display Modes
•
Operating Mode (Default),
•
Reset Mode (ENTER once, then Down)
•
Settings Mode (ENTER twice, then Down)
•
Configuration Mode (ENTER three times, then Down)
Menu Button: Press and release to navigate Config Menu, return to Main Menu
Right Button: Operating Mode - Max, Min, Del kW, Net kW, Total kW
Reset Mode - Yes, No
6–2
Settings Mode - On, Off, Settings
Config Mode - Password Digits, Available Values, Digits
Down Button: Scroll DOWN through Mode menus
Use Buttons in Modes of Operation:
Note
•
Operating Mode (default): View Parameter Values
•
Reset Mode: Reset Stored Max and Min Values
•
Settings Mode: View Meter Setting Parameters and Change Scroll Setting
•
Configuration Mode: Change Meter Configuration (Can be Password Protected)
The above is a brief overview of the use of the Buttons.
For Programming, refer to Chapter 7.
For complete Navigation Maps, refer to Appendix A of this manual.
6–3
6.2
% of Load Bar
The 10-segment LED bargraph at the bottom of the EPM2200 unit’s display provides a
graphic representation of Amps. The segments light according to the load in the %Load
Segment Table below.
When the Load is over 120% of Full Load, all segments flash “On” (1.5 secs) and “Off” (0.5
secs).
Table 6–1: % Load Segments
6–4
Segments
Load ≤ % Full Load
None
No Load
1
1%
1-2
15%
1-3
30%
1-4
45%
1-5
60%
1-6
72%
1-7
84%
1-8
96%
1-9
108%
1 - 10
120%
All Blink
>120%
6.3
Watt-hour Accuracy Testing (Verification)
To be certified for revenue metering, power providers and utility companies have to verify
that the billing energy meter will perform to the stated accuracy. To confirm the meter's
performance and calibration, power providers use field test standards to ensure that the
unit's energy measurements are correct. Since the EPM 2200 is a traceable revenue meter,
it contains a utility grade test pulse that can be used to gate an accuracy standard. This is
an essential feature required of all billing grade meters.
Watt-Hour
Test Pulse
FIGURE 6–3: Watt-hour Test Pulse
Refer to the figure below for an example of how this test works.
Refer to Table 6-2 below for the Wh/Pulse Constant for Accuracy Testing.
Test Pulses
Energy Pulses
Energy Standard
Comparator
Results
FIGURE 6–4: Using the Watt-Hour Test Pulse
6–5
6.3.1
Infrared & KYZ Pulse Constants for Accuracy Testing
Table 6–2: Infrared & KYZ Pulse Constants for Accuracy Testing
Voltage Level
Note
6–6
Class 10 Models
Class 2 Models
Below 150 V
0.2505759630
0.0501151926
Above 150 V
1.0023038521
0.2004607704
•
Minimum pulse width is 40 ms.
•
Refer to section 2.2 for Wh Pulse specifications.
Digital Energy
Multilin
Metering System
Chapter 7: Configuring the Meter
Using the Front Panel
Configuring the Meter Using the Front Panel
7.1
Overview
The EPM2200 front panel can be used to configure the meter. The EPM2200 has three
MODES:
• Operating Mode (Default)
• Reset Mode
• Configuration Mode.
The MENU, ENTER, DOWN and RIGHT buttons navigate through the modes and navigate
through all the screens in each mode.
Parameter
Designator
Reading Type
Indicator
% of Load Bar
Scale Selector
FIGURE 7–1: EPM2200 Label
7–1
CHAPTER 7: CONFIGURING THE METER USING THE FRONT PANEL
In this chapter, a typical set up will be demonstrated. Other settings are possible. The
complete Navigation Map for the Display Modes is in Appendix A of this manual. The meter
can also be configured with software (see GE Communicator EXT 3.0 Manual).
7–2
7.2
Start Up
Upon Power Up, the meter will display a sequence of screens. The sequence includes the
following screens:
•
Lamp Test Screen where all LEDs are lighted
•
Lamp Test Screen where all digits are lighted
•
Firmware Screen showing build number
•
Error Screen (if an error exists)
EPM2200 will then automatically Auto-Scroll the Parameter Designators on the right side
of the front panel. Values are displayed for each parameter.
The KILO or MEGA LED lights, showing the scale for the Wh, VARh and VAh readings.
An example of a Wh reading is shown here.
An example of a Wh reading is shown below.
FIGURE 7–2: Typical Wh Reading
The EPM2200 will continue to scroll through the Parameter Designators, providing
readings until one of the buttons on the front panel is pushed, causing the meter to enter
one of the other MODES.
7–3
7.3
Configuration
7.3.1
Main Menu
Push MENU from any of the Auto-Scrolling Readings. The MAIN MENU Screens appear.
The String for Reset Mode (rSt) appears (blinking) in the A Screen.
If you push DOWN, the MENU scrolls and the String for Configuration Mode (CFG)
appears
(blinking) in the A Screen.
If you push DOWN again, the String for Operating Mode (OPr) appears (blinking) in the
A Screen.
If you push DOWN again, the MENUscrolls back to Reset Mode (rSt).
If you push ENTER from the Main Menu, the meter enters the Mode that is in the A
Screen and is blinking. See Appendix A for Navigation Map.
FIGURE 7–3: Main Menu Screens
7.3.2
Reset Mode
If you push ENTER from the Main Menu, the meter enters the Mode that is in the A Screen
and is blinking. Reset Mode is the first mode to appear on the Main Menu. Push ENTER hile
(rSt) is in the A Screen and the “RESETALL? no” screen appears. Reset ALL resets all Max
and Min values. See Appendix A for Navigation Map.
.
7–4
•
If you push ENTER again, the Main Menu continues to scroll.
•
The DOWNbutton does not change the screen.
•
If you push the RIGHT button, the RESET All? YES screen appears.
.
•
To Reset All, you must enter a 4-digit Password, if Enabled in the software (see section
5.2.2).
•
Push ENTER; the following Password screen appears.
7.3.2.1 Enter Password (only if it has been enabled in software)
To enter a Password:
•
If PASSWORD is Enabled in the software (see section 5.2.2 to Enable/Change
Password), a screen appears requesting the Password. PASS appears in the A Screen
and 4 dashes in the B Screen. The LEFT digit is flashing.
•
Use the DOWN button to scroll from 0 to 9 for the flashing digit. When the correct
number appears for that digit, use the RIGHT button to move to the next digit.
Example: On the Password screens below:
• On the left screen, four dashes appear and the left digit is flashing.
• On the right screen, 2 digits have been entered and the third digit is flashing.
.
PASS or FAIL:
• When all 4 digits have been entered, push ENTER.
• If the correct Password has been entered, “rSt ALL donE” appears and the screen
returns to Auto-Scroll the Parameters. (In other Modes, the screen returns to the
screen to be changed. The left digit of the setting is flashing and the Program (PRG)
LED flashes on the left side of the meter face.)
7–5
.
• If an incorrect Password has been entered, “PASS ---- FAIL” appears and the
screen returns to Reset ALL? YES.
.
7.3.3
Configuration Mode
The following procedure describes how to navigate the configuration mode menu.
7–6
1.
Press the MENU Button from any of the auto-scrolling readings.
2.
Press DOWN to display the Configuration Mode (CFG) string in the “A” screen.
3.
Press ENTER to scroll through the configuration parameters, starting at the
SCrL Ct Pt screen.
4.
7.3.4
Push the DOWN Button to scroll all the parameters: scroll, CT, PT, connection
(Cnct) and port.
The active parameter is always flashing and displayed in the “A” screen.
Configuring the Scroll Feature
Use the following procedure to configure the scroll feature.
1.
Press the ENTER button to display the SCrL no message.
2.
Press the RIGHT button to change the display to SCrL YES as shown below.
FIGURE 7–4: Scroll Mode Configuration
When in scroll mode, the unit scrolls each parameter for 7 seconds on and 1 second off.
The meter can be configured through software to only display selected screens. In this
case, it will only scroll the selected displays.
3.
Push ENTER to select YES or no.
The screen scrolls to the CT parameters.
7.3.5
Programming the Configuration Mode Screens
Use the following procedure to program the screen for configuration mode.
1.
Press the DOWN or RIGHT button (for example, from the Ct-n message
below) to display the password screen, if enabled in the software.
2.
Use the DOWN and RIGHT buttons to enter the correct password (refer to
Reset Mode on page 7–4 for steps on password entry).
7–7
3.
Once the correct password is entered, push ENTER.
The Ct-n message will reappear, the PRG faceplate LED will flash, and the first
digit of the “B” screen will also flash.
4.
Use the DOWN button to change the first digit.
5.
Use the RIGHT button to select and change the successive digits.
6.
When the new value is entered, push ENTER twice.
This will display the Stor ALL? no screen.
7.
Use the RIGHT button to scroll to change the value from no to YES.
8.
When the Stor ALL? YES message is displayed, press ENTER to change the
setting.
The Stor ALL donE message will appear and the meter will reset.
7–8
7.3.6
Configuring the CT Setting
Use the following procedure to program the CT setting.
1.
Push the DOWN Button to scroll through the configuration mode parameters.
Press ENTER when Ct is the active parameter (i.e. it is in the “A” screen and flashing).
This will display the and the Ct-n (CT numerator) screen.
2.
Press ENTER again to change to display the Ct-d (CT denominator) screen.
The Ct-d value is preset to a 1 or 5 A at the factory and cannot be changed.
3.
Press ENTER again to select the to Ct-S (CT scaling) value.
The Ct-S value can be “1”, “10”, or “100”. Refer to Programming the Configuration Mode
Screens on page 7–7 for instructions on changing values.
7–9
Example settings for the Ct-S value are shown below:
200/5 A: set the Ct-n value for “200” and the Ct-S value for “1”
800/5 A: set the Ct-n value for “800” and the Ct-S value for “1”
2000/5 A: set the Ct-n value for “2000” and the Ct-S value for “1”.
10000/5 A: set the Ct-n value for “1000” and the Ct-S value for “10”.
The value for amps is a product of the Ct-n and the Ct-S values.
Note
4.
Press ENTER to scroll through the other CFG parameters.
Pressing DOWN or RIGHT displays the password screen (see Reset Mode on
page 7–4 for details).
5.
Press MENU to return to the main configuration menu.
Ct-n and Ct-S are dictated by Primary Voltage.
Ct-d is secondary Voltage.
Note
7.3.7
Configuring the PT Setting
Use the following procedure to program the PT setting.
1.
2.
Press ENTER when Pt is the "active" parameter (i.e. it is in the “A” screen and
flashing) as shown below.
This will display the Pt-n (PT numerator) screen.
7–10
3.
Press ENTER again to change to display the Pt-d (PT denominator) screen.
4.
Press ENTER again to select the to Pt-S (PT scaling) value.
The Pt-S value can be “1”, “10”, or “100”. Refer to Programming the Configuration Mode
Screens on page 7–7 for instructions on changing values.
Example settings for the Pt-n, Pt-d, and Pt-S values are shown below:
277/277 Volts:
Pt-n value is 277, Pt-d value is 277, Pt-Multiplier is 1
14400/120 Volts:
Pt-n value is 1440, Pt-d value is 120, Pt-S value is 10
138000/69 Volts:
345000/115 Volts:
345000/69 Volts:
5.
6.
Press DOWN or RIGHT to display the password screen (see Reset Mode on
7.
Press MENU to return to the Main Configuration Menu.
Pt-n and Pt-S are dictated by primary voltage.
Pt-d is secondary voltage.
Note
7.3.8
Configuring the Connection (Cnct) Setting
Use the following procedure to program the connection (Cnct) setting.
1.
Push the DOWN Button to scroll through the Configuration Mode parameters:
Scroll, CT, PT, Connection (Cnct), and Port. The "active" parameter is in the A
screen and is flashing
2.
Press ENTER when Cnct is the "active" parameter (i.e. it is in the “A” screen
and flashing).
This will display the Cnct (Connection) screen. To change this setting, use the RIGHT button
to scroll through the three settings. Select the setting that is right for your meter.
The possible Connection configurations are
• 3-element Wye (3 EL WYE)
• 2.5-element Wye (2.5EL WYE)
• 2 CT Delta (2 Ct deL)
as shown below:
7–11
3-Element Wye
7.3.9
2.5-Element Wye
2 CT Delta
3.
4.
Press DOWN or RIGHT to display the Password screen (see Reset Mode above
for details).
5.
Press MENU to return to the main Configuration menu.
Configuring the Communication Port Setting
Use the following procedure to program the communication port (POrt) settings.
1.
2.
Press ENTER when POrt is the active parameter (i.e. it is in the “A” screen and
flashing) as shown below.
The following parameters can be configured through the POrt menu
•
The meter Address (Adr, a 3-digit number).
•
The Baud Rate (bAUd). Select from “9600”, “19.2”, “38.4”, and
“57.6” for 9600, 19200, 38400, and 57600 kbps, respectively.
•
The Communications Protocol (Prot). Select “rtU” for Modbus
RTU, and “ASCI” for Modbus ASCII.
• The first POrt screen is Meter Address (Adr). The current address appears on the
screen. Follow the programming steps in section 7.3.5. Select a three-digit number
for the address.
7–12
Address 005
Refer to Programming the Configuration Mode Screens above for details on changing
values.
• The next POrt screen is the baud rate (bAUd). The current baud rate is displayed
on the “B” screen. Refer to Programming the Configuration Mode Screens above for
details on changing values. The possible baud rate screens are shown below.
• The final POrt screen is the Communications Protocol (Prot).
The current protocol is displayed on the “B” screen.
7–13
Refer to Programming the Configuration Mode Screens above for details on changing
values. The three protocol selections are shown below.
3.
4.
Press DOWN or RIGHT to display the Password screen (see Reset Mode on
5.
Press MENU to return to the main Configuration menu.
7.3.10 Operating Mode
Operating mode is the EPM 2200 meter’s default mode. If scrolling is enabled, the meter
automatically scrolls through these parameter screens after startup. The screen changes
every 7 seconds. Scrolling is suspended for 3 minutes after any button is pressed.
Push the DOWN button to scroll all the parameters in operating mode. The active
parameter has the indicator light next to it on the right face of the meter.
Push the RIGHT button to view additional displays for that parameter. A table of the
possible displays in the operating mode is below. Refer to Appendix A for a detailed
navigation map of the operating mode.
Table 7–1: Operating Mode Parameter Readings
Parameter designator
Available by Software
Option (see Order Code
table)
Note
7–14
Possible Readings
VOLTS L-N
A1, B1, C1
VOLTS_LN
VOLTS_LN_ MAX
VOLTS_LN_ MIN
VOLTS L-L
A1, B1, C1
VOLTS_LL
VOLTS_LL_ MAX
VOLTS_LL_ MIN
AMPS
A1, B1, C1
AMPS
AMPS_NEUTRAL
AMPS_MAX
AMPS_MIN
W/VAR/PF
B1, C1
W_VAR_PF
W_VAR_PF
_MAX_POS
W_VAR_PF
_MIN_POS
W_VAR_PF
_MAX_NEG
VA/Hz
B1, C1
VA_FREQ
VA_FREQ_ MAX
VA_FREQ_ MIN
Wh
C1
KWH_REC
KWH_DEL
KWH_NET
KWH_TOT
VARh
C1
KVARH_ POS
KVARH_ NEG
KVARH_ NET
KVARH_TOT
VAh
C1
KVAH
W_VAR_PF
_MIN_NEG
Readings or groups of readings are skipped if not applicable to the meter type or hookup,
or if explicitly disabled in the programmable settings.
Digital Energy
Multilin
Metering System
Appendix A: EPM2200 Navigation
Maps
EPM2200 Navigation Maps
Appendix A.1 Introduction
The EPM2200 meter can be configured and a variety of functions performed using the
buttons on the meter face.
•
An Overview of the Elements and Buttons on the meter face can be found in Chapter
6.
•
An Overview of Programming using the buttons can be found in Chapter 7.
•
The meter can also be programmed using software (see GE Communicator EXT 3.0
Manual).
APPENDIX A–1
APPENDIX A: EPM2200 NAVIGATION MAPS
Appendix A.2 Navigation Maps (Sheets 1 to 4)
The EPM2200 Navigation Maps begin on the next page.
They show in detail how to move from one screen to another and from one Display Mode
to another using the buttons on the face of the meter. All Display Modes will automatically
return to Operating Mode after 10 minutes with no user activity.
Appendix A.2.1 EPM2200 Navigation Map Titles:
Main Menu Screens (Sheet 1)
Operating Mode Screens (Sheet 2)
Reset Mode Screens (Sheet 3)
Configuration Mode Screens (Sheet 4)
APPENDIX A–2
APPENDIX A–3
APPENDIX A–4
APPENDIX A–5
APPENDIX A–6
Digital Energy
Multilin
Metering System
Appendix B: Modbus Mapping for
EPM2200
Modbus Mapping for EPM2200
Appendix B.1 Introduction
The Modbus Map for the EPM2200 Meter gives details and information about the possible
readings of the meter and about the programming of the meter. The EPM2200 can be
programmed using the buttons on the face plate of the meter (Chapter 7). The meter can
also be programmed using software. For a Programming Overview, see section 5.2 of this
manual. For further details see the GE Communicator EXT 3.0 Manual.
APPENDIX B–1
APPENDIX B: MODBUS MAPPING FOR EPM2200
Appendix B.2 Modbus Register Map Sections
The EPM2200 Modbus Register Map includes the following sections:
Fixed Data Section, Registers 1- 47, details the Meter’s Fixed Information described in
Section 7.2.
Meter Data Section, Registers 1000 - 5003, details the Meter’s Readings, including Primary
Readings, Energy Block, Demand Block, Maximum and Minimum Blocks, THD Block, Phase
Angle Block and Status Block. Operating Mode readings are described in Section 7.3.4.
Commands Section, Registers 20000 - 26011, details the Meter’s Resets Block,
Programming Block, Other Commands Block and Encryption Block.
Programmable Settings Section, Registers 30000 - 30067, details the Meter’s Basic Setups.
Secondary Readings Section, Registers 40001 - 40100, details the Meter’s Secondary
Readings Setups.
APPENDIX B–2
Appendix B.3 Data Formats
ASCII: ASCII characters packed 2 per register in high, low order and without any
termination charcters.
Example: “EPM2200” would be 4 registers containing 0x5378, 0x6172, 0x6B31,
0x3030.
SINT16/UINT16:16-bit signed/unsigned integer.
SINT32/UINT32:32-bit signed/unsigned integer spanning 2 registers. The lower-addressed
register is the high order half.
FLOAT:32-bit IEEE floating point number spanning 2 registers. The lower-addressed
register is the high order half (i.e., contains the exponent).
APPENDIX B–3
Appendix B.4 Floating Point Values
Floating Point Values are represented in the following format:
Register
0
Byte
1
0
1
4
3
2
1
0
7
6
5
7
6
5
4
3
2
1
0
7
6
Meaning
s
e
e
e
e
e
e
e
e
m m m m m m m m m m m m m m m m m m m m m m m
exponent
4
1
Bit
sign
5
0
3
2
1
0
7
6
5
4
3
2
1
0
mantissa
The formula to interpret a Floating Point Value is: -1sign x 2exponent-127 x 1.mantissa =
0x0C4E11DB9
-1sign x 2137-127 x 1.11000010001110111001
-1 x 210 x 1.75871956
-1800.929
Register
0x0C4E1
Byte
Bit
Meaning
0x01DB9
0x0C4
0x0E1
7
6
5
4
3
2
1
0
7
1
1
0
0
0
1
0
0
s
e
e
e
e
e
e
e
0x01D
0x0B9
6
5
4
3
2
1
0
7
6
5
4
3
2
1
0
7
6
5
4
3
2
1
0
1
1
1
0
0
0
0
1
0
0
0
1
1
1
0
1
1
0
1
1
1
0
0
1
e
m m m m m m m m m m m m m m m m m m m m m m m
sign
exponent
mantissa
1
0x089 = 137
0b11000010001110110111001
Formula Explanation
C4E11DB9 (hex)
11000100 11100001 00011101 10111001 (binary)
The sign of the Mantissa (and therefore the number) is 1, which represents a negative
value.
The Exponent is 10001001 (binary) or 137 decimal.
The Exponent is a value in excess of 127, so the Exponent value is 10.
The Mantissa is 11000010001110110111001 binary.
With the implied leading 1, the Mantissa is (1).C23B72 (hex).
The Floating Point Representation is therefore -1.75871956 x 210
Decimal equivalent: -1800.929
Note
Exponent = the whole number before the decimal point
Mantissa = the positive fraction after the decimal point
APPENDIX B–4
Appendix B.5 Modbus Register Map
Table Appendix B –1: Modbus Register Map (Sheet 1 of 7)
Hex
Decimal
Description1
Range6
Format
Units or
Resolution
#
R
e
g
Comments
Fixed Data Section
Identification Block
0000 - 0007 1
0008 - 000F 9
0010 - 0010 17
- 8
- 16
- 17
Meter Name
Meter Serial Number
Meter Type
ASCII 16 char
ASCII 16 char
UINT16 bit-mapped
none
none
-------t -----vvv
0011 - 0012 18
0013 - 0013 20
0014 - 0014 21
- 19
- 20
- 21
Firmware Version
Map Version
Meter Configuration
ASCII 4 char
UINT16 0 to 65535
UINT16 bit-mapped
none
none
-------- --ffffff
0015 - 0015 22
0016 - 0026 23
0027 - 002E 40
- 22
- 39
- 47
ASIC Version
Reserved
OEM Part Number
UINT16 0-65535
none
read-only
t=0
vvv = Software Option A1,
B1, or C1
ffffff = calibration
frequency (50 or 60)
8
8
1
2
1
1
1
17
8
47
Block Size:
Meter Data Section2
Primary Readings Block, 6 cycles (IEEE Floating
0383 - 0384 900
0385 - 0386 902
0387 - 0388 904
- 901
- 903
- 905
Watts, 3-Ph total
VARs, 3-Ph total
VAs, 3-Ph total
FLOAT
FLOAT
FLOAT
-9999 M to +9999 M
-9999 M to +9999 M
-9999 M to +9999 M
read-only
watts
VARs
VAs
Block Size:
Primary Readings Block, 60 cycles (IEEE Floating Point)
03E7 - 03E8 1000 - 1001 Volts A-N
03E9 - 03EA 1002 - 1003 Volts B-N
03EB - 03EC 1004 - 1005 Volts C-N
03ED - 03EE 1006 - 1007 Volts A-B
03EF - 03F0 1008 - 1009 Volts B-C
03F1 - 03F2 1010 - 1011 Volts C-A
03F3 - 03F4 1012 - 1013 Amps A
03F5 - 03F6 1014 - 1015 Amps B
03F7 - 03F8 1016 - 1017 Amps C
03F9 - 03FA 1018 - 1019 Watts, 3-Ph total
03FB - 03FC 1020 - 1021 VARs, 3-Ph total
03FD - 03FE 1022 - 1023 VAs, 3-Ph total
03FF - 0400 1024 - 1025 Power Factor, 3-Ph
total
0401 - 0402 1026 - 1027 Frequency
0403 - 0404 1028 - 1029 Neutral Current
2
2
2
6
read-only
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
-9999 M to +9999 M
-9999 M to +9999 M
-9999 M to +9999 M
-1.00 to +1.00
volts
volts
volts
volts
volts
volts
amps
amps
amps
watts
VARs
VAs
none
2
2
2
2
2
2
2
2
2
2
2
2
2
FLOAT
FLOAT
0 to 65.00
0 to 9999 M
Hz
amps
2
2
30
Block Size:
APPENDIX B–5
Hex
Decimal
Description1
Format
Range6
Units or
Resolution
Primary Energy Block
044B - 044C 1100
- 1101 W-hours, Received
0451 - 0452 1106 - 1107 W-hours, Total
SINT32 0 to 99999999 or
0 to -99999999
SINT32 0 to 99999999 or
0 to -99999999
SINT32 -99999999 to
99999999
SINT32 0 to 99999999
0453 - 0454 1108 - 1109 VAR-hours, Positive
SINT32 0 to 99999999
0455 - 0456 1110 - 1111 VAR-hours, Negative
SINT32 0 to -99999999
0457 - 0458 1112 - 1113 VAR-hours, Net
0459 - 045A 1114 - 1115 VAR-hours, Total
SINT32 -99999999 to
99999999
SINT32 0 to 99999999
045B - 045C 1116 - 1117 VA-hours, Total
SINT32 0 to 99999999
044D - 044E 1102 - 1103 W-hours, Delivered
044F - 0450 1104 - 1105 W-hours, Net
read-only
Wh per energy
format
Wh per energy
format
Wh per energy
format
Wh per energy
format
VARh per energy
format
* Wh received & delivered 2
always have opposite
* Wh received is positive 2
for "view as load",
delivered is positive for
2
"view as generator"
VARh per energy
format
VARh per energy
format
VARh per energy
format
VAh per energy
format
* resolution of digit before 2
decimal point = units, kilo,
or mega, per energy
2
format
2
* 5 to 8 digits
2
* decimal point implied,
per energy format
2
* see note 10
2
Block Size:
18
Primary Demand Block (IEEE Floating Point)
07CF
07D1
07D3
07D5
-
07D0
07D2
07D4
07D6
07D7 - 07D8
07D9 - 07DA
07DB - 07DC
07DD - 07DE
07DF - 07E0
07E1 - 07E2
2000 - 2001 Amps A, Average
2002 - 2003 Amps B, Average
2004 - 2005 Amps C, Average
2006 - 2007 Positive Watts, 3-Ph,
Average
2008 - 2009 Positive VARs, 3-Ph,
Average
2010 - 2011 Negative Watts, 3-Ph,
Average
2012 - 2013 Negative VARs, 3-Ph,
Average
2014 - 2015 VAs, 3-Ph, Average
2016 - 2017 Positive PF, 3-Ph,
Average
2018 - 2019 Negative PF, 3-PF,
Average
-
0BB8
0BBA
0BBC
0BBE
0BC0
0BC2
0BC4
3000
3002
3004
3006
3008
3010
3012
-
3001
3003
3005
3007
3009
3011
3013
0BC5 - 0BC6 3014 - 3015
0BC7 - 0BC8 3016 - 3017
0BC9 - 0BCA 3018 - 3019
0BCB - 0BCC 3020 - 3021
0BCD - 0BCE 3022 - 3023
APPENDIX B–6
Volts A-N, Minimum
Volts B-N, Minimum
Volts C-N, Minimum
Volts A-B, Minimum
Volts B-C, Minimum
Volts C-A, Minimum
Amps A, Minimum Avg
Demand
Amps B, Minimum Avg
Demand
Amps C, Minimum Avg
Demand
Positive Watts, 3-Ph,
Minimum Avg Demand
Positive VARs, 3-Ph,
Minimum Avg Demand
Negative Watts, 3-Ph,
Minimum Avg Demand
read-only
FLOAT
FLOAT
FLOAT
FLOAT
0 to 9999 M
0 to 9999 M
0 to 9999 M
-9999 M to +9999 M
amps
amps
amps
watts
FLOAT
-9999 M to +9999 M
VARs
2
FLOAT
-9999 M to +9999 M
watts
2
FLOAT
-9999 M to +9999 M
VARs
2
FLOAT
FLOAT
-9999 M to +9999 M
-1.00 to +1.00
VAs
none
2
2
FLOAT
-1.00 to +1.00
none
2
Block Size:
Primary Minimum Block (IEEE Floating Point)
0BB7
0BB9
0BBB
0BBD
0BBF
0BC1
0BC3
#
R
e
g
Comments
2
2
2
2
20
read-only
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
volts
volts
volts
volts
volts
volts
amps
2
2
2
2
2
2
2
FLOAT
0 to 9999 M
amps
2
FLOAT
0 to 9999 M
amps
2
FLOAT
0 to +9999 M
watts
2
FLOAT
0 to +9999 M
VARs
2
FLOAT
0 to +9999 M
watts
2
Hex
Decimal
Description1
0BCF - 0BD0 3024 - 3025 Negative VARs, 3-Ph,
Minimum Avg Demand
0BD1 - 0BD2 3026 - 3027 VAs, 3-Ph, Minimum
Avg Demand
0BD3 - 0BD4 3028 - 3029 Positive Power Factor,
3-Ph, Minimum Avg
Demand
0BD5 - 0BD6 3030 - 3031 Negative Power Factor,
3-Ph, Minimum Avg
Demand
0BD7 - 0BD8 3032 - 3033 Frequency, Minimum
Units or
Resolution
Range6
Format
FLOAT
0 to +9999 M
VARs
2
FLOAT
-9999 M to +9999 M
VAs
2
FLOAT
-1.00 to +1.00
none
2
FLOAT
-1.00 to +1.00
none
2
FLOAT
0 to 65.00
Hz
2
34
Block Size:
Primary Maximum Block (IEEE Floating Point)
0C1B
0C1D
0C1F
0C21
0C23
0C25
0C27
-
0C1C
0C1E
0C20
0C22
0C24
0C26
0C28
3100
3102
3104
3106
3108
3110
3112
-
3101
3103
3105
3107
3109
3111
3113
0C29 - 0C2A 3114 - 3115
0C2B - 0C2C 3116 - 3117
0C2D - 0C2E 3118 - 3119
0C2F - 0C30 3120 - 3121
0C31 - 0C32 3122 - 3123
0C33 - 0C34 3124 - 3125
0C35 - 0C36 3126 - 3127
0C37 - 0C38 3128 - 3129
0C39 - 0C3A 3130 - 3131
0C3B - 0C3C 3132 - 3133
Volts A-N, Maximum
Volts B-N, Maximum
Volts C-N, Maximum
Volts A-B, Maximum
Volts B-C, Maximum
Volts C-A, Maximum
Amps A, Maximum Avg
Demand
Amps B, Maximum Avg
Demand
Amps C, Maximum Avg
Demand
Positive Watts, 3-Ph,
Maximum Avg
Demand
Positive VARs, 3-Ph,
Maximum Avg
Demand
Negative Watts, 3-Ph,
Maximum Avg
Demand
Negative VARs, 3-Ph,
Maximum Avg
Demand
VAs, 3-Ph, Maximum
Avg Demand
Positive Power Factor,
3-Ph, Maximum Avg
Demand
Negative Power Factor,
3-Ph, Maximum Avg
Demand
Frequency, Maximum
read-only
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
volts
volts
volts
volts
volts
volts
amps
FLOAT
0 to 9999 M
amps
2
FLOAT
0 to 9999 M
amps
2
FLOAT
0 to +9999 M
watts
2
FLOAT
0 to +9999 M
VARs
2
FLOAT
0 to +9999 M
watts
2
FLOAT
0 to +9999 M
VARs
2
FLOAT
-9999 M to +9999 M
VAs
2
FLOAT
-1.00 to +1.00
none
2
FLOAT
-1.00 to +1.00
none
2
FLOAT
0 to 65.00
Hz
Phase Angle Block14
-
1003
1004
1005
1006
1007
1008
4100
4101
4102
4103
4104
4105
-
4100
4101
4102
4103
4104
4105
Phase A Current
Phase B Current
Phase C Current
Angle, Volts A-B
Angle, Volts B-C
Angle, Volts C-A
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
-1800 to +1800
-1800 to +1800
-1800 to +1800
-1800 to +1800
-1800 to +1800
-1800 to +1800
read-only
0.1 degree
0.1 degree
0.1 degree
0.1 degree
0.1 degree
0.1 degree
Block Size:
2
2
2
2
2
2
2
2
34
Block Size:
1003
1004
1005
1006
1007
1008
#
R
e
g
Comments
1
1
1
1
1
1
6
APPENDIX B–7
Hex
Decimal
Description1
Format
Range6
Units or
Resolution
Status Block
1387 - 1387 5000
- 5000 Meter Status
UINT16 bit-mapped
1388 - 1388 5001 - 5001 Not Used
N/A
1389 - 138A 5002 - 5003 Time Since Reset
UINT32 0 to 4294967294
#
R
e
g
Comments
read-only
--exnpch
ssssssss
exnpch = EEPROM block 1
OK flags (e=energy,
x=max, n=min,
p=programmable settings,
c=calibration, h=header),
ssssssss = state (1=Run,
2=Limp, 10=Prog Set
Update via buttons,
12=Prog Set Update via
communication port.)
4 msec
wraps around after max
count
Block Size:
2
4
Commands Section4
Resets Block9
4E1F - 4E1F 20000 - 20000 Reset Max/Min Blocks UINT16 password5
4E20 - 4E20 20001 - 20001 Reset Energy
UINT16 password5
Accumulators
Meter Programming Block
55EF - 55EF 22000 - 22000 Initiate Programmable
Settings Update
55F0 - 55F0 22001 - 22001 Terminate
Programmable
Settings Update3
55F1 - 55F1 22002 - 22002 Calculate
Programmable
Settings Checksum3
55F2 - 55F2 22003 - 22003 Programmable
Settings Checksum3
UINT16 password5
UINT16 any value
UINT16
UINT16
55F3 - 55F3 22004 - 22004 Write New Password3 UINT16 0000 to 9999
59D7 - 59D7 23000 - 23000 Initiate Meter
Firmware
Reprogramming
Other Commands Block
61A7 - 61A7 25000 - 25000 Force Meter Restart
write-only
Block Size:
2
read/conditional write
meter enters PS update
mode
meter leaves PS update
mode via reset
6
read/write
causes a watchdog reset, 1
always reads 0
Block Size:
658F - 659A 26000 - 26011 Perform a Secure
Operation
APPENDIX B–8
UINT16
1
1
Block Size:
Encryption Block
1
meter calculates
1
checksum on RAM copy of
PS block
read/write checksum
1
register; PS block saved in
8
EEPROM on write
write-only register; always 1
reads zero
UINT16 password5
UINT16 password5
1
1
1
read/write
encrypted command to
12
read password or change
meter type
Block Size:
12
Hex
Decimal
Description1
Range6
Format
Units or
Resolution
#
R
e
g
Comments
Programmable Settings Section (See note 15)
Basic Setups Block
752F - 752F 30000 - 30000 CT multiplier &
denominator
UINT16 bit-mapped
7530
7531
7532
7533
UINT16
UINT16
UINT16
UINT16
-
7530
7531
7532
7533
30001
30002
30003
30004
-
30001
30002
30003
30004
CT numerator
PT numerator
PT denominator
PT multiplier & hookup
1 to 9999
1 to 9999
1 to 9999
bit-mapped
7534 - 7534 30005 - 30005 Averaging Method
UINT16 bit-mapped
7535 - 7535 30006 - 30006 Power & Energy
Format
UINT16 bit-mapped
7536 - 7536 30007 - 30007 Operating Mode
Screen Enables
UINT16 bit-mapped
7537 - 753D 30008 - 30014 Reserved
753E - 753E 30015 - 30015 User Settings Flags
UINT16 bit-mapped
753F - 753F 30016 - 30016 Full Scale Current (for
load % bargraph)
UINT16 0 to 9999
7540 - 7547 30017 - 30024 Meter Designation
7548 - 7548 30025 - 30025 Not Used
ASCII
16 char
write only in PS update
mode
dddddddd
high byte is denominator
mmmmmmmm (5, read-only),
low byte is multiplier (1, 10,
or 100)
none
none
none
mmmmmmmm MMMMmmmmmmmm is
MMMMhhhh
PT multiplier (1, 10, 100,
1000),
hhhh is hookup
enumeration (0 = 3
element wye[9S], 1 = delta
2 CTs[5S], 3 = 2.5 element
--iiiiii b----sss
iiiiii = interval (5,15,30,60)
b = 0-block or 1-rolling
sss = # subintervals
(1,2,3,4)
pppp--nn -eee- pppp = power scale (0ddd
unit, 3-kilo, 6-mega, 8auto)
nn = number of energy
digits (5-8 --> 0-3)
eee = energy scale (0-unit,
3-kilo, 6-mega)
ddd = energy digits after
decimal point (0-6)
See note 10.
1
1
1
1
1
1
1
00000000
eeeeeeee
eeeeeeee = op mode
1
screen rows on(1) or off(0),
rows top to bottom are
bits low order to high order
7
---g--nn srp--wf- g = enable alternate full
1
scale bargraph current
(1=on, 0=off)
nn = number of phases for
voltage & current screens
(3=ABC, 2=AB, 1=A, 0=ABC)
s = scroll (1=on, 0=off)
r = password for reset in
use (1=on, 0=off)
p = password for
configuration in use (1=on,
0=off)
w = pwr dir (0-view as
load, 1-view as generator)
f = flip power factor sign
(1=yes, 0=no)
none
If non-zero and user
1
settings bit g is set, this
value replaces CT
numerator in the full scale
current calculation.
none
8
1
APPENDIX B–9
Hex
Decimal
Description1
Range6
Format
Units or
Resolution
#
R
e
g
Comments
1
dddd = reply delay (* 50
msec)
ppp = protocol (1-Modbus
RTU, 2-Modbus ASCII)
bbb = baud rate (1-9600,
2-19200, 4-38400, 657600)
1
1
7549 - 7549 30026 - 30026 COM2 setup
UINT16 bit-mapped
----dddd -pppbbb
754A - 754A 30027 - 30027 COM2 address
754B - 754B 30028 - 30028 Not Used
UINT16 1 to 247
N/A
none
754C - 754C 30029 - 30029 Not Used
N/A
1
754D - 754D 30030 - 30030 Not Used
N/A
1
754E - 754E 30031 - 30031 Not Used
N/A
1
754F - 754F 30032 - 30032 Not Used
N/A
1
7550
7555
755A
755F
7564
7569
756E
N/A
N/A
N/A
N/A
N/A
N/A
N/A
5
5
5
5
5
5
5
68
-
7554
7559
755E
7563
7568
756D
7572
30033
30038
30043
30048
30053
30058
30063
-
30037
30042
30047
30052
30057
30062
30067
Not Used
Not Used
Not Used
Not Used
Not Used
Not Used
Not Used
Block Size:
Secondary Readings Section
12-Bit Block
9C40 - 9C40 40001 - 40001 System Sanity
Indicator
9C41 - 9C41 40002 - 40002 Volts A-N
9C42 - 9C42 40003 - 40003 Volts B-N
9C43 - 9C43 40004 - 40004 Volts C-N
9C44 - 9C44 40005 - 40005 Amps A
UINT16 0 or 1
none
UINT16
UINT16
UINT16
UINT16
volts
volts
volts
amps
9C45 - 9C45 40006 - 40006 Amps B
9C46 - 9C46 40007 - 40007 Amps C
9C47 - 9C47 40008 - 40008 Watts, 3-Ph total
UINT16 0 to 4095
UINT16 0 to 4095
UINT16 0 to 4095
amps
amps
watts
9C48 - 9C48 40009 - 40009 VARs, 3-Ph total
9C49 - 9C49 40010 - 40010 VAs, 3-Ph total
9C4A - 9C4A 40011 - 40011 Power Factor, 3-Ph
total
UINT16 0 to 4095
UINT16 2047 to 4095
UINT16 1047 to 3047
VARs
VAs
none
APPENDIX B–10
2047 to 4095
2047 to 4095
2047 to 4095
0 to 4095
read-only except as
noted
0 indicates proper meter
operation
2047= 0, 4095= +150
volts = 150 * (register 2047) / 2047
0= -10, 2047= 0, 4095=
+10
amps = 10 * (register 2047) / 2047
1
1
1
1
1
1
1
0= -3000, 2047= 0, 4095= 1
+3000
watts, VARs, VAs =
1
3000 * (register - 2047) / 1
1047= -1, 2047= 0, 3047= 1
+1
pf =
(register - 2047) / 1000
Hex
Decimal
Description1
Units or
Resolution
Range6
Format
9C4B - 9C4B 40012 - 40012 Frequency
UINT16 0 to 2730
Hz
9C4C
9C4D
9C4E
9C4F
9C50
9C51
9C52
9C53
9C54
9C55
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT32
volts
volts
volts
none
none
none
none
none
none
Wh per energy
format
Wh per energy
format
-
9C4C
9C4D
9C4E
9C4F
9C50
9C51
9C52
9C53
9C54
9C56
40013
40014
40015
40016
40017
40018
40019
40020
40021
40022
-
40013
40014
40015
40016
40017
40018
40019
40020
40021
40023
Volts A-B
Volts B-C
Volts C-A
CT numerator
CT multiplier
CT denominator
PT numerator
PT multiplier
PT denominator
W-hours, Positive
2047 to 4095
2047 to 4095
2047 to 4095
1 to 9999
1, 10, 100
1 or 5
1 to 9999
1, 10, 100
1 to 9999
0 to 99999999
9C57 - 9C58 40024 - 40025 W-hours, Negative
UINT32 0 to 99999999
9C59 - 9C5A 40026 - 40027 VAR-hours, Positive
UINT32 0 to 99999999
9C5B - 9C5C 40028 - 40029 VAR-hours, Negative
UINT32 0 to 99999999
9C5D - 9C5E 40030 - 40031 VA-hours
UINT32 0 to 99999999
9C5F - 9C5F 40032 - 40032 Neutral Current
9C60 - 9CA2 40033 - 40099 Reserved
9CA3 - 9CA3 40100 - 40100 Reset Energy
Accumulators
UINT16 0 to 4095
N/A
N/A
UINT16 password5
#
R
e
g
Comments
0= 45 or less, 2047= 60,
2730= 65 or more
freq = 45 + ((register /
4095) * 30)
2047= 0, 4095= +300
volts = 300 * (register 2047) / 2047
1
* decimal point implied,
per energy format
2
1
1
1
CT = numerator *
1
multiplier / denominator 1
1
PT = numerator * multiplier 1
/ denominator
1
1
* 5 to 8 digits
2
VARh per energy
format
VARh per energy
format
* resolution of digit before 2
decimal point = units, kilo,
or mega, per energy
2
format
VAh per energy
format
amps
none
* see note 10
2
see Amps A/B/C above
1
67
write-only register; always 1
reads as 0
Block Size:
100
ASCII
ASCII characters packed 2 per register in high, low order and without any termination
characters. For example, "EPM2200" would be 4 registers containing 0x5378, 0x6172,
0x6B31, 0x3030.
SINT16/UINT16
16-bit signed / unsigned integer.
SINT32/UINT32
32-bit signed / unsigned integer spanning 2 registers. The lower-addressed register is the
high order half.
FLOAT
32-bit IEEE floating point number spanning 2 registers. The lower-addressed register is the
high order half (i.e., contains the exponent).
1
All registers not explicitly listed in the table read as 0. Writes to these registers will be
accepted but won't actually change the register (since it doesn’t exist).
2
Meter Data Section items read as 0 until first readings are available or if the meter is not in
operating mode. Writes to these registers will be accepted but won't actually change the
register.
3
Register valid only in programmable settings update mode. In other modes these registers
read as 0 and return an illegal data address exception if a write is attempted..
4
Meter command registers always read as 0. They may be written only when the meter is in
a suitable mode. The registers return an illegal data address exception if a write is
attempted in an incorrect mode.
5
If the password is incorrect, a valid response is returned but the command is not executed.
Use 5555 for the password if passwords are disabled in the programmable settings.
APPENDIX B–11
6
M denotes a 1,000,000 multiplier.
7
Not applicable to EPM2200
8
Writing this register causes data to be saved permanently in EEPROM. If there is an error
while saving, a slave device failure exception is returned and programmable settings mode
automatically terminates via reset.
9
Reset commands make no sense if the meter state is LIMP. An illegal function exception will
be returned.
10
Energy registers should be reset after a format change.
11
N/A
13
N/A
All 3 voltage angles are measured for Wye and Delta hookups. For 2.5 Element, Vac is
measured and Vab & Vbc are calculated. If a voltage phase is missing, the two voltage
angles in which it participates are set to zero. A and C phase current angles are measured
for all hookups. B phase current angle is measured for Wye and is zero for other hookups. If
a voltage phase is missing, its current angle is zero.
If any register in the programmable settings section is set to a value other than the
acceptable value then the meter will stay in LIMP mode. Please read the comments section
or the range for each register in programmable settings section for acceptable settings.
N/A
14
15
16
APPENDIX B–12

EPM 2200

Transcription

Similar documents

SpectraFoo - Metric Halo

SC76 with 5 accessories v01.qxd

Smart Metering Solution 3 - Ingeneo Advanced Metering

Miglin-Beitler Skyneedle Fact Sheet

News Report – The Hitavada News Report – Lokmat “ Hello “ Nagpur

funJoin Play Meter on facebook

Wednesday`s Words

Cereal - Shibboleth!